Document and Entity Information
Document and Entity Information - USD ($) | 12 Months Ended | ||
Dec. 31, 2018 | Jan. 31, 2019 | Jun. 30, 2018 | |
Entity Registrant Name | EXELON CORP | ||
Entity Central Index Key | 1,109,357 | ||
Document Type | 10-K | ||
Document Period End Date | Dec. 31, 2018 | ||
Amendment Flag | false | ||
Document Fiscal Year Focus | 2,018 | ||
Document Fiscal Period Focus | FY | ||
Current Fiscal Year End Date | --12-31 | ||
Entity Well-known Seasoned Issuer | Yes | ||
Entity Voluntary Filers | No | ||
Entity Current Reporting Status | Yes | ||
Entity Filer Category | Large Accelerated Filer | ||
Entity Common Stock Shares Outstanding | 969,745,933 | ||
Entity Public Float | $ 41,118,095,431 | ||
Exelon Generation Co L L C [Member] | |||
Entity Registrant Name | EXELON GENERATION CO LLC | ||
Entity Central Index Key | 1,168,165 | ||
Entity Filer Category | Non-accelerated Filer | ||
Commonwealth Edison Co [Member] | |||
Entity Registrant Name | COMMONWEALTH EDISON CO | ||
Entity Central Index Key | 22,606 | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Common Stock Shares Outstanding | 127,021,331 | ||
PECO Energy Co [Member] | |||
Entity Registrant Name | PECO ENERGY CO | ||
Entity Central Index Key | 78,100 | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Common Stock Shares Outstanding | 170,478,507 | ||
Baltimore Gas and Electric Company [Member] | |||
Entity Registrant Name | BALTIMORE GAS AND ELECTRIC | ||
Entity Central Index Key | 9,466 | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Common Stock Shares Outstanding | 1,000 | ||
Pepco Holdings LLC [Member] | |||
Entity Registrant Name | PEPCO HOLDINGS LLC | ||
Entity Central Index Key | 1,135,971 | ||
Entity Filer Category | Non-accelerated Filer | ||
Potomac Electric Power Company [Member] | |||
Entity Registrant Name | POTOMAC ELECTRIC POWER CO | ||
Entity Central Index Key | 79,732 | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Common Stock Shares Outstanding | 100 | ||
Delmarva Power & Light Company [Member] | |||
Entity Registrant Name | DELMARVA POWER & LIGHT CO /DE/ | ||
Entity Central Index Key | 27,879 | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Common Stock Shares Outstanding | 1,000 | ||
Atlantic City Electric Company [Member] | |||
Entity Registrant Name | ATLANTIC CITY ELECTRIC CO | ||
Entity Central Index Key | 8,192 | ||
Entity Filer Category | Non-accelerated Filer | ||
Entity Common Stock Shares Outstanding | 8,546,017 |
Consolidated Statements of Oper
Consolidated Statements of Operations and Comprehensive Income - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Operating revenues | |||||
Competitive businesses revenues | $ 19,168 | $ 17,394 | $ 16,330 | ||
Rate-regulated utility revenues | 16,879 | 15,964 | 14,988 | ||
Electric operating revenues | 0 | 0 | |||
Natural gas operating revenues | 0 | 0 | |||
Revenues from alternative revenue programs | (62) | 207 | 48 | ||
Operating revenues from affiliates | 0 | 0 | |||
Total operating revenues | 35,985 | 33,565 | 31,366 | ||
Operating expenses | |||||
Competitive businesses purchased power and fuel | 11,679 | 9,668 | 8,817 | ||
Rate-regulated utility purchased power and fuel | 4,991 | 4,367 | 3,823 | ||
Operating and maintenance | 9,337 | 10,025 | 9,954 | ||
Depreciation and amortization | 4,353 | 3,828 | 3,936 | ||
Taxes other than income | 1,783 | 1,731 | 1,576 | ||
Total operating expenses | 32,143 | 29,619 | 28,106 | ||
Gain (loss) on sales of assets and businesses | 56 | 3 | (48) | ||
Bargain purchase gain | 0 | 233 | 0 | ||
Gain on deconsolidation of business | 0 | 213 | 0 | ||
Operating income (loss) | 3,898 | 4,395 | 3,212 | ||
Other income and (deductions) | |||||
Interest expense, net | (1,529) | (1,524) | (1,495) | ||
Interest expense to affiliates | (25) | (36) | (41) | ||
Other, net | (112) | 947 | 297 | ||
Total other income and (deductions) | (1,666) | (613) | (1,239) | ||
Income (loss) before income taxes | 2,232 | 3,782 | 1,973 | ||
Income taxes | 120 | (126) | 753 | ||
Equity in losses of unconsolidated affiliates | (28) | (32) | (24) | ||
Net income (loss) | 2,084 | 3,876 | 1,196 | ||
Net income (loss) attributable to noncontrolling interests and/or preference stock dividends | 74 | 90 | 75 | ||
Net income (loss) attributable to common shareholders | 2,010 | 3,786 | 1,121 | ||
Other comprehensive income (loss), net of income taxes | |||||
Prior service benefit reclassified to periodic benefit cost | (66) | (56) | (48) | ||
Actuarial loss reclassified to periodic cost | 247 | 197 | 184 | ||
Pension and non-pension postretirement benefit plan valuation adjustment | (143) | 10 | (181) | ||
Unrealized gain on cash flow hedges | 12 | 3 | 2 | ||
Unrealized gain on marketable securities | 0 | 6 | 1 | ||
Unrealized gain (loss) on investments in unconsolidated affiliates | 2 | 4 | (4) | ||
Unrealized (loss) gain on foreign currency translation | (10) | 7 | 10 | ||
Other comprehensive income (loss) | 42 | 171 | (36) | ||
Comprehensive income (loss) | 2,126 | 4,047 | 1,160 | ||
Comprehensive income attributable to noncontrolling interests and/or preference stock dividends | 75 | 88 | 75 | ||
Comprehensive income (loss) attributable to common shareholders | $ 2,051 | $ 3,959 | $ 1,085 | ||
Average shares of common stock outstanding: | |||||
Weighted Average Number of Shares Outstanding, Basic | 967 | 947 | 924 | ||
Weighted Average Number of Shares Outstanding, Diluted | 969 | 949 | 927 | ||
Earnings per average common share: | |||||
Earnings Per Share, Basic | $ 2.08 | $ 4 | $ 1.21 | ||
Earnings Per Share, Diluted | $ 2.07 | $ 3.99 | $ 1.21 | ||
Exelon Generation Co L L C [Member] | |||||
Operating revenues | |||||
Competitive businesses revenues | $ 19,169 | $ 17,385 | $ 16,318 | ||
Rate-regulated utility revenues | 0 | 0 | |||
Electric operating revenues | 0 | 0 | |||
Natural gas operating revenues | 0 | 0 | |||
Revenues from alternative revenue programs | 0 | 0 | |||
Operating revenues from affiliates | 1,268 | 1,115 | 1,439 | ||
Total operating revenues | 20,437 | 18,500 | 17,757 | ||
Operating expenses | |||||
Competitive businesses purchased power and fuel | 11,679 | 9,671 | 8,818 | ||
Purchased power and/or fuel from affiliates | 14 | 19 | 12 | ||
Operating and maintenance | 4,803 | 5,602 | 5,000 | ||
Operating and maintenance from affiliates | 661 | 697 | 663 | ||
Depreciation and amortization | 1,797 | 1,457 | 1,879 | ||
Taxes other than income | 556 | 555 | 506 | ||
Total operating expenses | 19,510 | 18,001 | 16,878 | ||
Gain (loss) on sales of assets and businesses | 48 | 2 | (59) | ||
Bargain purchase gain | 0 | 233 | 0 | ||
Gain on deconsolidation of business | 0 | 213 | 0 | ||
Operating income (loss) | 975 | 947 | 820 | ||
Other income and (deductions) | |||||
Interest expense, net | (396) | (401) | (325) | ||
Interest expense to affiliates | (36) | (39) | (39) | ||
Other, net | (178) | 948 | 401 | ||
Total other income and (deductions) | (610) | 508 | 37 | ||
Income (loss) before income taxes | 365 | 1,455 | 857 | ||
Income taxes | (108) | (1,376) | 282 | ||
Equity in losses of unconsolidated affiliates | (30) | (33) | (25) | ||
Net income (loss) | 443 | 2,798 | 550 | ||
Net income (loss) attributable to noncontrolling interests | 73 | 88 | 67 | ||
Net income (loss) attributable to membership interest | 370 | 2,710 | 483 | ||
Other comprehensive income (loss), net of income taxes | |||||
Unrealized gain on cash flow hedges | 12 | 3 | 2 | ||
Unrealized gain on marketable securities | 0 | 1 | 1 | ||
Unrealized gain (loss) on investments in unconsolidated affiliates | 1 | 4 | (4) | ||
Unrealized (loss) gain on foreign currency translation | (10) | 7 | 10 | ||
Other comprehensive income (loss) | 3 | 15 | 9 | ||
Comprehensive income (loss) | 446 | 2,813 | 559 | ||
Comprehensive income attributable to noncontrolling interests and/or preference stock dividends | 74 | 86 | 67 | ||
Comprehensive income (loss) attributable to common shareholders | 372 | 2,727 | 492 | ||
Commonwealth Edison Co [Member] | |||||
Operating revenues | |||||
Competitive businesses revenues | 0 | 0 | |||
Rate-regulated utility revenues | 0 | 0 | |||
Electric operating revenues | 5,884 | 5,478 | 5,263 | ||
Natural gas operating revenues | 0 | 0 | |||
Revenues from alternative revenue programs | (29) | 43 | (24) | ||
Operating revenues from affiliates | 27 | 15 | 15 | ||
Total operating revenues | 5,882 | 5,536 | 5,254 | ||
Operating expenses | |||||
Purchased power | 1,626 | 1,533 | 1,411 | ||
Purchased power and/or fuel from affiliates | 529 | 108 | 47 | ||
Operating and maintenance | 1,068 | 1,157 | 1,303 | ||
Operating and maintenance from affiliates | 267 | 270 | 227 | ||
Depreciation and amortization | 940 | 850 | 775 | ||
Taxes other than income | 311 | 296 | 293 | ||
Total operating expenses | 4,741 | 4,214 | 4,056 | ||
Gain (loss) on sales of assets and businesses | 5 | 1 | 7 | ||
Operating income (loss) | 1,146 | 1,323 | 1,205 | ||
Other income and (deductions) | |||||
Interest expense, net | (334) | (348) | (448) | ||
Interest expense to affiliates | (13) | (13) | (13) | ||
Other, net | 33 | 22 | (65) | ||
Total other income and (deductions) | (314) | (339) | (526) | ||
Income (loss) before income taxes | 832 | 984 | 679 | ||
Income taxes | 168 | 417 | 301 | ||
Net income (loss) | 664 | 567 | 378 | ||
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income (loss) | 664 | 567 | 378 | ||
PECO Energy Co [Member] | |||||
Operating revenues | |||||
Competitive businesses revenues | 0 | 0 | |||
Rate-regulated utility revenues | 0 | 0 | |||
Electric operating revenues | 2,469 | 2,369 | 2,524 | ||
Natural gas operating revenues | 568 | 494 | 462 | ||
Revenues from alternative revenue programs | (7) | 0 | 0 | ||
Operating revenues from affiliates | 8 | 7 | 8 | ||
Total operating revenues | 3,038 | 2,870 | 2,994 | ||
Operating expenses | |||||
Purchased power | 734 | 648 | 598 | ||
Purchased fuel | 230 | 186 | 162 | ||
Purchased power and/or fuel from affiliates | 126 | 135 | 287 | ||
Operating and maintenance | 742 | 657 | 665 | ||
Operating and maintenance from affiliates | 156 | 149 | 146 | ||
Depreciation and amortization | 301 | 286 | 270 | ||
Taxes other than income | 163 | 154 | 164 | ||
Total operating expenses | 2,452 | 2,215 | 2,292 | ||
Gain (loss) on sales of assets and businesses | 1 | 0 | 0 | ||
Operating income (loss) | 587 | 655 | 702 | ||
Other income and (deductions) | |||||
Interest expense, net | (115) | (115) | (111) | ||
Interest expense to affiliates | (14) | (11) | (12) | ||
Other, net | 8 | 9 | 8 | ||
Total other income and (deductions) | (121) | (117) | (115) | ||
Income (loss) before income taxes | 466 | 538 | 587 | ||
Income taxes | 6 | 104 | 149 | ||
Net income (loss) | 460 | 434 | 438 | ||
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income (loss) | 460 | 434 | 438 | ||
Baltimore Gas and Electric Company [Member] | |||||
Operating revenues | |||||
Competitive businesses revenues | 0 | 0 | |||
Rate-regulated utility revenues | 0 | 0 | |||
Electric operating revenues | 2,428 | 2,384 | 2,531 | ||
Natural gas operating revenues | 738 | 652 | 628 | ||
Revenues from alternative revenue programs | (26) | 124 | 53 | ||
Operating revenues from affiliates | 29 | 16 | 21 | ||
Total operating revenues | 3,169 | 3,176 | 3,233 | ||
Operating expenses | |||||
Purchased power | 671 | 566 | 528 | ||
Purchased fuel | 254 | 183 | 162 | ||
Purchased power and/or fuel from affiliates | 257 | 384 | 604 | ||
Operating and maintenance | 615 | 563 | 605 | ||
Operating and maintenance from affiliates | 162 | 153 | 132 | ||
Depreciation and amortization | 483 | 473 | 423 | ||
Taxes other than income | 254 | 240 | 229 | ||
Total operating expenses | 2,696 | 2,562 | 2,683 | ||
Gain (loss) on sales of assets and businesses | 1 | 0 | 0 | ||
Operating income (loss) | 474 | 614 | 550 | ||
Other income and (deductions) | |||||
Interest expense, net | (106) | (95) | (87) | ||
Interest expense to affiliates | 0 | (10) | (16) | ||
Other, net | 19 | 16 | 21 | ||
Total other income and (deductions) | (87) | (89) | (82) | ||
Income (loss) before income taxes | 387 | 525 | 468 | ||
Income taxes | 74 | 218 | 174 | ||
Net income (loss) | 313 | 307 | 294 | ||
Preference stock dividends | 0 | 0 | 8 | ||
Net income (loss) attributable to common shareholders | 313 | 307 | 286 | ||
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income (loss) | 313 | 307 | 294 | ||
Comprehensive income attributable to noncontrolling interests and/or preference stock dividends | 0 | 0 | 8 | ||
Comprehensive income (loss) attributable to common shareholders | 313 | 307 | 286 | ||
Pepco Holdings LLC [Member] | |||||
Operating revenues | |||||
Electric operating revenues | 4,609 | 4,428 | |||
Natural gas operating revenues | 181 | 161 | |||
Revenues from alternative revenue programs | 0 | 40 | |||
Operating revenues from affiliates | 15 | 50 | |||
Total operating revenues | 4,805 | 4,679 | |||
Operating expenses | |||||
Purchased power | 1,387 | 1,182 | |||
Purchased fuel | 89 | 71 | |||
Purchased power and/or fuel from affiliates | 355 | 463 | |||
Operating and maintenance | 978 | 918 | |||
Operating and maintenance from affiliates | 152 | 150 | |||
Depreciation and amortization | 740 | 675 | |||
Taxes other than income | 455 | 452 | |||
Total operating expenses | 4,156 | 3,911 | |||
Gain (loss) on sales of assets and businesses | 1 | 1 | |||
Operating income (loss) | 650 | 769 | |||
Other income and (deductions) | |||||
Interest expense, net | (261) | (245) | |||
Other, net | 43 | 54 | |||
Total other income and (deductions) | (218) | (191) | |||
Income (loss) before income taxes | 432 | 578 | |||
Income taxes | 35 | 217 | |||
Equity in losses of unconsolidated affiliates | 1 | 1 | |||
Net income (loss) | 398 | 362 | |||
Net income (loss) attributable to membership interest | 398 | 362 | |||
Other comprehensive income (loss), net of income taxes | |||||
Actuarial loss reclassified to periodic cost | 0 | 0 | |||
Other comprehensive income (loss) | 0 | 0 | |||
Comprehensive income (loss) attributable to common shareholders | 398 | 362 | |||
Pepco Holdings LLC [Member] | Predecessor [Member] | |||||
Operating revenues | |||||
Competitive businesses revenues | $ 0 | ||||
Rate-regulated utility revenues | 0 | ||||
Electric operating revenues | 1,122 | ||||
Natural gas operating revenues | 57 | ||||
Revenues from alternative revenue programs | (26) | ||||
Operating revenues from affiliates | 0 | ||||
Total operating revenues | 1,153 | ||||
Operating expenses | |||||
Purchased power | 471 | ||||
Purchased fuel | 26 | ||||
Purchased power and/or fuel from affiliates | 0 | ||||
Operating and maintenance | 294 | ||||
Operating and maintenance from affiliates | 0 | ||||
Depreciation and amortization | 152 | ||||
Taxes other than income | 105 | ||||
Total operating expenses | 1,048 | ||||
Gain (loss) on sales of assets and businesses | 0 | ||||
Operating income (loss) | 105 | ||||
Other income and (deductions) | |||||
Interest expense, net | (65) | ||||
Other, net | (4) | ||||
Total other income and (deductions) | (69) | ||||
Income (loss) before income taxes | 36 | ||||
Income taxes | 17 | ||||
Equity in losses of unconsolidated affiliates | 0 | ||||
Net income (loss) | 19 | ||||
Net income (loss) attributable to membership interest | 19 | ||||
Other comprehensive income (loss), net of income taxes | |||||
Actuarial loss reclassified to periodic cost | 1 | ||||
Other comprehensive income (loss) | 1 | ||||
Comprehensive income (loss) attributable to common shareholders | $ 20 | ||||
Pepco Holdings LLC [Member] | Successor [Member] | |||||
Operating revenues | |||||
Competitive businesses revenues | $ 0 | 0 | |||
Rate-regulated utility revenues | 0 | 0 | |||
Electric operating revenues | 3,463 | 4,428 | |||
Natural gas operating revenues | 92 | 161 | |||
Revenues from alternative revenue programs | 43 | 40 | |||
Operating revenues from affiliates | 45 | 15 | 50 | ||
Total operating revenues | 3,643 | 4,679 | |||
Operating expenses | |||||
Purchased power | 925 | ||||
Purchased fuel | 36 | ||||
Purchased power and/or fuel from affiliates | 486 | ||||
Operating and maintenance | 1,144 | ||||
Operating and maintenance from affiliates | 89 | 152 | 150 | ||
Depreciation and amortization | 515 | ||||
Taxes other than income | 354 | ||||
Total operating expenses | 3,549 | ||||
Gain (loss) on sales of assets and businesses | (1) | ||||
Operating income (loss) | 93 | ||||
Other income and (deductions) | |||||
Interest expense, net | (195) | ||||
Other, net | 44 | ||||
Total other income and (deductions) | (151) | ||||
Income (loss) before income taxes | (58) | ||||
Income taxes | 3 | ||||
Equity in losses of unconsolidated affiliates | 0 | ||||
Net income (loss) | (61) | ||||
Net income (loss) attributable to membership interest | (61) | ||||
Other comprehensive income (loss), net of income taxes | |||||
Actuarial loss reclassified to periodic cost | 0 | ||||
Other comprehensive income (loss) | 0 | ||||
Comprehensive income (loss) attributable to common shareholders | $ (61) | ||||
Potomac Electric Power Company [Member] | |||||
Operating revenues | |||||
Competitive businesses revenues | 0 | 0 | |||
Rate-regulated utility revenues | 0 | 0 | |||
Electric operating revenues | 2,233 | 2,126 | 2,167 | ||
Natural gas operating revenues | 0 | 0 | |||
Revenues from alternative revenue programs | 0 | 26 | 14 | ||
Operating revenues from affiliates | 6 | 6 | 5 | ||
Total operating revenues | 2,239 | 2,158 | 2,186 | ||
Operating expenses | |||||
Purchased power | 448 | 359 | 411 | ||
Purchased power and/or fuel from affiliates | 206 | 255 | 295 | ||
Operating and maintenance | 275 | 396 | 607 | ||
Operating and maintenance from affiliates | 226 | 58 | 35 | ||
Depreciation and amortization | 385 | 321 | 295 | ||
Taxes other than income | 379 | 371 | 377 | ||
Total operating expenses | 1,919 | 1,760 | 2,020 | ||
Gain (loss) on sales of assets and businesses | 0 | 1 | 8 | ||
Operating income (loss) | 320 | 399 | 174 | ||
Other income and (deductions) | |||||
Interest expense, net | (128) | (121) | (127) | ||
Other, net | 31 | 32 | 36 | ||
Total other income and (deductions) | (97) | (89) | (91) | ||
Income (loss) before income taxes | 223 | 310 | 83 | ||
Income taxes | 13 | 105 | 41 | ||
Net income (loss) | 210 | 205 | 42 | ||
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income (loss) | 210 | 205 | 42 | ||
Delmarva Power & Light Company [Member] | |||||
Operating revenues | |||||
Competitive businesses revenues | 0 | 0 | |||
Rate-regulated utility revenues | 0 | 0 | |||
Electric operating revenues | 1,139 | 1,125 | 1,128 | ||
Natural gas operating revenues | 181 | 161 | 148 | ||
Revenues from alternative revenue programs | 4 | 6 | (6) | ||
Operating revenues from affiliates | 8 | 8 | 7 | ||
Total operating revenues | 1,332 | 1,300 | 1,277 | ||
Operating expenses | |||||
Purchased power | 352 | 282 | 369 | ||
Purchased fuel | 89 | 71 | 60 | ||
Purchased power and/or fuel from affiliates | 120 | 179 | 154 | ||
Operating and maintenance | 182 | 283 | 422 | ||
Operating and maintenance from affiliates | 162 | 32 | 19 | ||
Depreciation and amortization | 182 | 167 | 157 | ||
Taxes other than income | 56 | 57 | 55 | ||
Total operating expenses | 1,143 | 1,071 | 1,236 | ||
Gain (loss) on sales of assets and businesses | 1 | 0 | 9 | ||
Operating income (loss) | 190 | 229 | 50 | ||
Other income and (deductions) | |||||
Interest expense, net | (58) | (51) | (50) | ||
Other, net | 10 | 14 | 13 | ||
Total other income and (deductions) | (48) | (37) | (37) | ||
Income (loss) before income taxes | 142 | 192 | 13 | ||
Income taxes | 22 | 71 | 22 | ||
Net income (loss) | 120 | 121 | (9) | ||
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income (loss) | 120 | 121 | (9) | ||
Atlantic City Electric Company [Member] | |||||
Operating revenues | |||||
Competitive businesses revenues | 0 | 0 | |||
Rate-regulated utility revenues | 0 | 0 | |||
Electric operating revenues | 1,237 | 1,176 | 1,245 | ||
Natural gas operating revenues | 0 | 0 | |||
Revenues from alternative revenue programs | (4) | 8 | 9 | ||
Operating revenues from affiliates | 3 | 2 | 3 | ||
Total operating revenues | 1,236 | 1,186 | 1,257 | ||
Operating expenses | |||||
Purchased power | 587 | 541 | 614 | ||
Purchased power and/or fuel from affiliates | 29 | 29 | 37 | ||
Operating and maintenance | 188 | 279 | 410 | ||
Operating and maintenance from affiliates | 142 | 28 | 18 | ||
Depreciation and amortization | 136 | 146 | 165 | ||
Taxes other than income | 5 | 6 | 7 | ||
Total operating expenses | 1,087 | 1,029 | 1,251 | ||
Gain (loss) on sales of assets and businesses | 0 | 0 | 1 | ||
Operating income (loss) | 149 | 157 | 7 | ||
Other income and (deductions) | |||||
Interest expense, net | (64) | (61) | (62) | ||
Other, net | 2 | 7 | 9 | ||
Total other income and (deductions) | (62) | (54) | (53) | ||
Income (loss) before income taxes | 87 | 103 | (46) | ||
Income taxes | 12 | 26 | (4) | ||
Net income (loss) | 75 | 77 | (42) | ||
Other comprehensive income (loss), net of income taxes | |||||
Comprehensive income (loss) | $ 75 | $ 77 | $ (42) |
Consolidated Statements of Cash
Consolidated Statements of Cash Flows - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Cash flows from operating activities | |||
Net Income (Loss) | $ 2,084 | $ 3,876 | $ 1,196 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 5,971 | 5,427 | 5,576 |
Impairment losses of long-lived assets, intangibles and regulatory assets | 50 | 573 | 306 |
Gain on deconsolidation of business | 0 | (213) | 0 |
(Gain) Loss on sales of assets and businesses | (56) | (3) | 48 |
Bargain purchase gain | 0 | (233) | 0 |
Deferred income taxes and amortization of investment tax credits | (106) | (362) | 656 |
Net fair value changes related to derivatives | 294 | 151 | 24 |
Net realized and unrealized (gains) losses on nuclear decommissioning trust fund investments | 303 | (616) | (229) |
Other non-cash operating activities | 1,124 | 721 | 1,333 |
Changes in assets and liabilities: | |||
Accounts receivable | (565) | (470) | (432) |
Inventories | (37) | (72) | 7 |
Accounts payable and accrued expenses | 551 | (388) | 771 |
Option premiums received (paid), net | (43) | 28 | (66) |
Collateral (posted) received, net | 82 | (158) | 931 |
Income taxes | 340 | 299 | 576 |
Pension and non-pension postretirement benefit contributions | (383) | (405) | (397) |
Deposit with IRS | 0 | 0 | (1,250) |
Other assets and liabilities | (965) | (675) | (589) |
Net cash flows provided by (used in) operating activities | 8,644 | 7,480 | 8,461 |
Cash flows from investing activities | |||
Capital expenditures | (7,594) | (7,584) | (8,553) |
Proceeds from termination of direct financing lease investment | 0 | 0 | 360 |
Proceeds from nuclear decommissioning trust fund sales | 8,762 | 7,845 | 9,496 |
Investment in nuclear decommissioning trust funds | (8,997) | (8,113) | (9,738) |
Reduction of restricted cash from deconsolidation of business | 0 | (87) | 0 |
Acquisitions of businesses, net | (154) | (208) | (6,923) |
Proceeds from sales of long-lived assets | 91 | 219 | 61 |
Other investing activities | 58 | (43) | (153) |
Net cash flows provided by (used in) investing activities | (7,834) | (7,971) | (15,450) |
Cash flows from financing activities | |||
Changes in short-term borrowings | (338) | (261) | (353) |
Proceeds from short-term borrowings with maturities greater than 90 days | 126 | 621 | 240 |
Repayments on short-term borrowings with maturities greater than 90 days | (1) | (700) | (462) |
Issuance of long-term debt | 3,115 | 3,470 | 4,716 |
Retirement of long-term debt | (1,786) | (2,490) | (1,936) |
Retirement of long-term debt to financing trust | 0 | (250) | 0 |
Common stock issued from treasury stock | 0 | 1,150 | 0 |
Redemption of preference stock | 0 | 0 | (190) |
Dividends paid on common stock | (1,332) | (1,236) | (1,166) |
Proceeds from employee stock plans | 105 | 150 | 55 |
Sale of noncontrolling interest | 0 | 396 | 372 |
Other financing activities | (108) | (83) | (85) |
Net cash flows provided by (used in) financing activities | (219) | 767 | 1,191 |
Increase (Decrease) in cash, cash equivalents and restricted cash | 591 | 276 | (5,798) |
Cash, cash equivalents, and restricted cash at beginning of period | 1,190 | 914 | 6,712 |
Cash, cash equivalents, and restricted cash at end of period | 1,781 | 1,190 | 914 |
Exelon Generation Co L L C [Member] | |||
Cash flows from operating activities | |||
Net Income (Loss) | 443 | 2,798 | 550 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 3,415 | 3,056 | 3,519 |
Impairment losses of long-lived assets, intangibles and regulatory assets | 50 | 510 | 243 |
Gain on deconsolidation of business | 0 | (213) | 0 |
(Gain) Loss on sales of assets and businesses | (48) | (2) | 59 |
Bargain purchase gain | 0 | (233) | 0 |
Deferred income taxes and amortization of investment tax credits | (451) | (2,023) | (277) |
Net fair value changes related to derivatives | 307 | 167 | 40 |
Net realized and unrealized (gains) losses on nuclear decommissioning trust fund investments | 303 | (616) | (229) |
Other non-cash operating activities | 298 | 112 | 15 |
Changes in assets and liabilities: | |||
Accounts receivable | (359) | (320) | (152) |
Receivables from and payables to affiliates, net | 8 | (7) | (21) |
Inventories | (12) | (29) | (4) |
Accounts payable and accrued expenses | 376 | 4 | 29 |
Option premiums received (paid), net | (43) | 28 | (66) |
Collateral (posted) received, net | 64 | (129) | 923 |
Income taxes | (193) | 496 | 182 |
Pension and non-pension postretirement benefit contributions | (139) | (148) | (152) |
Other assets and liabilities | (158) | (152) | (217) |
Net cash flows provided by (used in) operating activities | 3,861 | 3,299 | 4,442 |
Cash flows from investing activities | |||
Capital expenditures | (2,242) | (2,259) | (3,078) |
Proceeds from nuclear decommissioning trust fund sales | 8,762 | 7,845 | 9,496 |
Investment in nuclear decommissioning trust funds | (8,997) | (8,113) | (9,738) |
Reduction of restricted cash from deconsolidation of business | 0 | (87) | 0 |
Acquisitions of businesses, net | (154) | (208) | (293) |
Proceeds from sales of long-lived assets | 90 | 218 | 37 |
Other investing activities | 10 | (58) | (240) |
Net cash flows provided by (used in) investing activities | (2,531) | (2,662) | (3,816) |
Cash flows from financing activities | |||
Changes in short-term borrowings | 0 | (620) | 620 |
Proceeds from short-term borrowings with maturities greater than 90 days | 1 | 121 | 240 |
Repayments on short-term borrowings with maturities greater than 90 days | (1) | (200) | (162) |
Issuance of long-term debt | 15 | 1,645 | 388 |
Retirement of long-term debt | (141) | (1,261) | (202) |
Changes in Exelon intercompany money pool | 46 | (1) | (1,191) |
Distributions to member | (1,001) | (659) | (922) |
Contributions from member | 155 | 102 | 142 |
Sale of noncontrolling interest | 0 | 396 | 372 |
Other financing activities | (55) | (54) | (19) |
Net cash flows provided by (used in) financing activities | (981) | (531) | (734) |
Increase (Decrease) in cash, cash equivalents and restricted cash | 349 | 106 | (108) |
Cash, cash equivalents, and restricted cash at beginning of period | 554 | 448 | 556 |
Cash, cash equivalents, and restricted cash at end of period | 903 | 554 | 448 |
Commonwealth Edison Co [Member] | |||
Cash flows from operating activities | |||
Net Income (Loss) | 664 | 567 | 378 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 940 | 850 | 775 |
Deferred income taxes and amortization of investment tax credits | 259 | 659 | 439 |
Other non-cash operating activities | 242 | 164 | 215 |
Changes in assets and liabilities: | |||
Accounts receivable | (136) | (59) | (25) |
Receivables from and payables to affiliates, net | 26 | 8 | 3 |
Inventories | 1 | 4 | 1 |
Accounts payable and accrued expenses | 70 | (297) | 339 |
Collateral (posted) received, net | 11 | (26) | 7 |
Income taxes | 62 | (308) | 306 |
Pension and non-pension postretirement benefit contributions | (42) | (41) | (38) |
Other assets and liabilities | (348) | 6 | 105 |
Net cash flows provided by (used in) operating activities | 1,749 | 1,527 | 2,505 |
Cash flows from investing activities | |||
Capital expenditures | (2,126) | (2,250) | (2,734) |
Other investing activities | 29 | 20 | 49 |
Net cash flows provided by (used in) investing activities | (2,097) | (2,230) | (2,685) |
Cash flows from financing activities | |||
Changes in short-term borrowings | 0 | 0 | (294) |
Issuance of long-term debt | 1,350 | 1,000 | 1,200 |
Retirement of long-term debt | (840) | (425) | (665) |
Dividends paid on common stock | (459) | (422) | (369) |
Contributions from parent | 500 | 651 | 315 |
Other financing activities | (17) | (15) | (18) |
Net cash flows provided by (used in) financing activities | 534 | 789 | 169 |
Increase (Decrease) in cash, cash equivalents and restricted cash | 186 | 86 | (11) |
Cash, cash equivalents, and restricted cash at beginning of period | 144 | 58 | 69 |
Cash, cash equivalents, and restricted cash at end of period | 330 | 144 | 58 |
PECO Energy Co [Member] | |||
Cash flows from operating activities | |||
Net Income (Loss) | 460 | 434 | 438 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 301 | 286 | 270 |
Deferred income taxes and amortization of investment tax credits | (5) | 19 | 78 |
Other non-cash operating activities | 51 | 54 | 65 |
Changes in assets and liabilities: | |||
Accounts receivable | (74) | (44) | (71) |
Receivables from and payables to affiliates, net | 7 | (6) | 6 |
Inventories | (14) | 1 | 6 |
Accounts payable and accrued expenses | (3) | 6 | 67 |
Income taxes | 15 | 34 | 8 |
Pension and non-pension postretirement benefit contributions | (28) | (24) | (30) |
Other assets and liabilities | 29 | (5) | (8) |
Net cash flows provided by (used in) operating activities | 739 | 755 | 829 |
Cash flows from investing activities | |||
Capital expenditures | (849) | (732) | (686) |
Changes in Exelon intercompany money pool | 0 | 131 | (131) |
Other investing activities | 9 | 4 | 20 |
Net cash flows provided by (used in) investing activities | (840) | (597) | (797) |
Cash flows from financing activities | |||
Issuance of long-term debt | 700 | 325 | 300 |
Retirement of long-term debt | (500) | 0 | (300) |
Dividends paid on common stock | (306) | (288) | (277) |
Contributions from parent | 89 | 16 | 18 |
Other financing activities | (22) | (3) | (4) |
Net cash flows provided by (used in) financing activities | (39) | 50 | (263) |
Increase (Decrease) in cash, cash equivalents and restricted cash | (140) | 208 | (231) |
Cash, cash equivalents, and restricted cash at beginning of period | 275 | 67 | 298 |
Cash, cash equivalents, and restricted cash at end of period | 135 | 275 | 67 |
Baltimore Gas and Electric Company [Member] | |||
Cash flows from operating activities | |||
Net Income (Loss) | 313 | 307 | 294 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 483 | 473 | 423 |
Impairment losses of long-lived assets, intangibles and regulatory assets | 0 | 7 | 52 |
Deferred income taxes and amortization of investment tax credits | 76 | 145 | 118 |
Other non-cash operating activities | 58 | 65 | 88 |
Changes in assets and liabilities: | |||
Accounts receivable | 8 | (5) | (98) |
Receivables from and payables to affiliates, net | 12 | (4) | 3 |
Inventories | 2 | (9) | 1 |
Accounts payable and accrued expenses | (1) | (15) | 138 |
Collateral (posted) received, net | 4 | 0 | 0 |
Income taxes | (20) | 60 | 18 |
Pension and non-pension postretirement benefit contributions | (54) | (53) | (49) |
Other assets and liabilities | (92) | (150) | (43) |
Net cash flows provided by (used in) operating activities | 789 | 821 | 945 |
Cash flows from investing activities | |||
Capital expenditures | (959) | (882) | (934) |
Other investing activities | 9 | 7 | 24 |
Net cash flows provided by (used in) investing activities | (950) | (875) | (910) |
Cash flows from financing activities | |||
Changes in short-term borrowings | (42) | 32 | (165) |
Issuance of long-term debt | 300 | 300 | 850 |
Retirement of long-term debt | 0 | (41) | (379) |
Retirement of long-term debt to financing trust | 0 | (250) | 0 |
Redemption of preference stock | 0 | 0 | (190) |
Dividends paid on preferred securities | 0 | 0 | (8) |
Dividends paid on common stock | (209) | (198) | (179) |
Contributions from parent | 109 | 184 | 61 |
Other financing activities | (2) | (5) | (11) |
Net cash flows provided by (used in) financing activities | 156 | 22 | (21) |
Increase (Decrease) in cash, cash equivalents and restricted cash | (5) | (32) | 14 |
Cash, cash equivalents, and restricted cash at beginning of period | 18 | 50 | 36 |
Cash, cash equivalents, and restricted cash at end of period | 13 | 18 | 50 |
Pepco Holdings LLC [Member] | |||
Cash flows from operating activities | |||
Net Income (Loss) | 398 | 362 | |
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 740 | 675 | |
Impairment losses of long-lived assets, intangibles and regulatory assets | 0 | 52 | |
Deferred income taxes and amortization of investment tax credits | 32 | 252 | |
Net fair value changes related to derivatives | 0 | 0 | |
Other non-cash operating activities | (143) | (58) | |
Changes in assets and liabilities: | |||
Accounts receivable | 2 | 26 | |
Receivables from and payables to affiliates, net | 8 | (2) | |
Inventories | 14 | 37 | |
Accounts payable and accrued expenses | 45 | (106) | |
Income taxes | 34 | 79 | |
Pension and non-pension postretirement benefit contributions | 74 | 99 | |
Other assets and liabilities | 178 | 258 | |
Net cash flows provided by (used in) operating activities | 1,132 | 950 | |
Cash flows from investing activities | |||
Capital expenditures | (1,375) | (1,396) | |
Purchases of investments | 0 | 0 | |
Other investing activities | 4 | (1) | |
Net cash flows provided by (used in) investing activities | (1,371) | (1,397) | |
Cash flows from financing activities | |||
Changes in short-term borrowings | (296) | 328 | |
Proceeds from short-term borrowings with maturities greater than 90 days | 125 | 0 | |
Repayments on short-term borrowings with maturities greater than 90 days | 0 | (500) | |
Issuance of long-term debt | 750 | 202 | |
Retirement of long-term debt | (299) | (169) | |
Changes in Exelon intercompany money pool | 0 | 0 | |
Distributions to member | (326) | (311) | |
Proceeds from employee stock plans | 0 | 0 | |
Contributions from parent | 385 | 758 | |
Other financing activities | (9) | (2) | |
Net cash flows provided by (used in) financing activities | 330 | 306 | |
Increase (Decrease) in cash, cash equivalents and restricted cash | 91 | (141) | |
Cash, cash equivalents, and restricted cash at beginning of period | 95 | 236 | |
Cash, cash equivalents, and restricted cash at end of period | 186 | 95 | 236 |
Pepco Holdings LLC [Member] | Predecessor [Member] | |||
Cash flows from financing activities | |||
Cash, cash equivalents, and restricted cash at beginning of period | 58 | ||
Pepco Holdings LLC [Member] | Successor [Member] | |||
Cash flows from financing activities | |||
Cash, cash equivalents, and restricted cash at beginning of period | 236 | ||
Cash, cash equivalents, and restricted cash at end of period | 236 | ||
Potomac Electric Power Company [Member] | |||
Cash flows from operating activities | |||
Net Income (Loss) | 210 | 205 | 42 |
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 385 | 321 | 295 |
Impairment losses of long-lived assets, intangibles and regulatory assets | 0 | 14 | 0 |
Deferred income taxes and amortization of investment tax credits | (18) | 113 | 153 |
Other non-cash operating activities | 60 | (6) | 175 |
Changes in assets and liabilities: | |||
Accounts receivable | (5) | (20) | (41) |
Receivables from and payables to affiliates, net | (17) | 0 | 44 |
Inventories | (6) | (24) | 1 |
Accounts payable and accrued expenses | 59 | (63) | 32 |
Income taxes | (13) | 81 | 110 |
Pension and non-pension postretirement benefit contributions | (17) | (72) | (32) |
Other assets and liabilities | (164) | (142) | (128) |
Net cash flows provided by (used in) operating activities | 474 | 407 | 651 |
Cash flows from investing activities | |||
Capital expenditures | (656) | (628) | (586) |
Purchases of investments | 0 | 0 | (30) |
Other investing activities | 2 | 0 | 0 |
Net cash flows provided by (used in) investing activities | (654) | (628) | (616) |
Cash flows from financing activities | |||
Changes in short-term borrowings | 14 | 3 | (41) |
Issuance of long-term debt | 200 | 202 | 4 |
Retirement of long-term debt | (14) | (13) | (11) |
Dividends paid on common stock | (169) | (133) | (136) |
Contributions from parent | 166 | 161 | 187 |
Other financing activities | (4) | (1) | (3) |
Net cash flows provided by (used in) financing activities | 193 | 219 | 0 |
Increase (Decrease) in cash, cash equivalents and restricted cash | 13 | (2) | 35 |
Cash, cash equivalents, and restricted cash at beginning of period | 40 | 42 | 7 |
Cash, cash equivalents, and restricted cash at end of period | 53 | 40 | 42 |
Delmarva Power & Light Company [Member] | |||
Cash flows from operating activities | |||
Net Income (Loss) | 120 | 121 | (9) |
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 182 | 167 | 157 |
Impairment losses of long-lived assets, intangibles and regulatory assets | 0 | 6 | 0 |
Deferred income taxes and amortization of investment tax credits | 24 | 89 | 109 |
Other non-cash operating activities | 24 | 9 | 114 |
Changes in assets and liabilities: | |||
Accounts receivable | 8 | (22) | (5) |
Receivables from and payables to affiliates, net | (9) | 11 | 13 |
Inventories | (3) | (5) | 0 |
Accounts payable and accrued expenses | 11 | (8) | (4) |
Collateral (posted) received, net | 0 | 0 | 1 |
Income taxes | 2 | 26 | 28 |
Pension and non-pension postretirement benefit contributions | 0 | (2) | (22) |
Other assets and liabilities | (7) | (71) | (72) |
Net cash flows provided by (used in) operating activities | 352 | 321 | 310 |
Cash flows from investing activities | |||
Capital expenditures | (364) | (428) | (349) |
Other investing activities | 2 | (1) | 13 |
Net cash flows provided by (used in) investing activities | (362) | (429) | (336) |
Cash flows from financing activities | |||
Changes in short-term borrowings | (216) | 216 | (105) |
Issuance of long-term debt | 200 | 0 | 175 |
Retirement of long-term debt | (4) | (40) | (100) |
Dividends paid on common stock | (96) | (112) | (54) |
Contributions from parent | 150 | 0 | 152 |
Other financing activities | (2) | 0 | (1) |
Net cash flows provided by (used in) financing activities | 32 | 64 | 67 |
Increase (Decrease) in cash, cash equivalents and restricted cash | 22 | (44) | 41 |
Cash, cash equivalents, and restricted cash at beginning of period | 2 | 46 | 5 |
Cash, cash equivalents, and restricted cash at end of period | 24 | 2 | 46 |
Atlantic City Electric Company [Member] | |||
Cash flows from operating activities | |||
Net Income (Loss) | 75 | 77 | (42) |
Adjustments to reconcile net income to net cash flows provided by operating activities: | |||
Depreciation, amortization and accretion, including nuclear fuel and energy contract amortization | 136 | 146 | 165 |
Impairment losses of long-lived assets, intangibles and regulatory assets | 0 | 7 | 0 |
Deferred income taxes and amortization of investment tax credits | 25 | 32 | 22 |
Other non-cash operating activities | 24 | 17 | 155 |
Changes in assets and liabilities: | |||
Accounts receivable | (8) | 14 | (8) |
Receivables from and payables to affiliates, net | 1 | 0 | 13 |
Inventories | (4) | (7) | (1) |
Accounts payable and accrued expenses | (7) | (2) | 9 |
Income taxes | (2) | (11) | 174 |
Pension and non-pension postretirement benefit contributions | (6) | (20) | (17) |
Other assets and liabilities | (6) | (47) | (85) |
Net cash flows provided by (used in) operating activities | 228 | 206 | 385 |
Cash flows from investing activities | |||
Capital expenditures | (335) | (312) | (311) |
Other investing activities | 1 | (1) | 4 |
Net cash flows provided by (used in) investing activities | (334) | (313) | (307) |
Cash flows from financing activities | |||
Changes in short-term borrowings | (94) | 108 | (5) |
Proceeds from short-term borrowings with maturities greater than 90 days | 125 | 0 | 0 |
Issuance of long-term debt | 350 | 0 | 0 |
Retirement of long-term debt | (281) | (35) | (48) |
Dividends paid on common stock | (59) | (68) | (63) |
Contributions from parent | 67 | 0 | 139 |
Other financing activities | (3) | 0 | (1) |
Net cash flows provided by (used in) financing activities | 105 | 5 | 22 |
Increase (Decrease) in cash, cash equivalents and restricted cash | (1) | (102) | 100 |
Cash, cash equivalents, and restricted cash at beginning of period | 31 | 133 | 33 |
Cash, cash equivalents, and restricted cash at end of period | $ 30 | $ 31 | $ 133 |
Consolidated Balance Sheets
Consolidated Balance Sheets - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Current assets | |||
Cash and cash equivalents | $ 1,349 | $ 898 | |
Restricted cash and cash equivalents | 247 | 207 | |
Accounts receivable, net | |||
Customer | 4,607 | 4,445 | |
Other | 1,256 | 1,132 | |
Mark-to-market derivative assets, current | 804 | 976 | |
Unamortized energy contract assets, current | 48 | 60 | |
Inventories, net | |||
Energy Related Inventory, Other Fossil Fuel | 334 | 340 | |
Materials and supplies | 1,351 | 1,311 | |
Regulatory assets, current | 1,222 | 1,267 | |
Assets held for sale | 904 | 0 | |
Other | 1,238 | 1,260 | |
Total current assets | 13,360 | 11,896 | |
Property, plant and equipment, net | 76,707 | 74,202 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 8,237 | 8,021 | |
Nuclear decommissioning trust funds | 11,661 | 13,272 | |
Investments | 625 | 640 | |
Goodwill | 6,677 | 6,677 | |
Mark-to-market derivative assets, noncurrent | 452 | 337 | |
Unamortized energy contract assets, noncurrent | 372 | 395 | |
Other | 1,575 | 1,330 | |
Total deferred debits and other assets | 29,599 | 30,672 | |
Total assets | [1] | 119,666 | 116,770 |
Current liabilities | |||
Short-term borrowings | 714 | 929 | |
Long-term debt due within one year | 1,349 | 2,088 | |
Accounts payable | 3,800 | 3,532 | |
Accrued expenses | 2,112 | 1,837 | |
Payables to affiliates, current | 5 | 5 | |
Regulatory Liability, Current | 644 | 523 | |
Mark-to-market derivative liabilities, current | 475 | 232 | |
Unamortized energy contract liabilities, current | 149 | 231 | |
Renewable energy credit obligation | 344 | 352 | |
Liabilities held for sale | 777 | 0 | |
Other | 1,035 | 1,069 | |
Total current liabilities | 11,404 | 10,798 | |
Long-term debt | 34,075 | 32,176 | |
Long-term debt to financing trusts | 390 | 389 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 11,330 | 11,235 | |
Asset retirement obligations, noncurrent | 9,679 | 10,029 | |
Pension obligations | 3,988 | 3,736 | |
Non-pension postretirement benefit obligations | 1,928 | 2,093 | |
Spent nuclear fuel obligation | 1,171 | 1,147 | |
Regulatory liabilities, noncurrent | 9,559 | 9,865 | |
Mark-to-market derivative liabilities, noncurrent | 479 | 409 | |
Unamortized energy contract liabilities, noncurrent | 463 | 609 | |
Other | 2,130 | 2,097 | |
Total deferred credits and other liabilities | 40,727 | 41,220 | |
Total liabilities | [1] | 86,596 | 84,583 |
Commitments and Contingencies | |||
Shareholders’ equity | |||
Common stock | 19,116 | 18,964 | |
Treasury stock, at cost | (123) | (123) | |
Retained earnings | 14,766 | 14,081 | |
Accumulated other comprehensive income (loss), net | (2,995) | (3,026) | |
Total shareholders’ equity | 30,764 | 29,896 | |
Member’s equity | |||
Noncontrolling interests | 2,306 | 2,291 | |
Total equity | 33,070 | 32,187 | |
Total liabilities and equity | 119,666 | 116,770 | |
Variable Interest Entity, Consolidated, Assets, Not Pledged | 9,667 | 9,597 | |
Variable Interest Entity, Consolidated, Liabilities, No Recourse | 3,548 | 3,618 | |
Exelon Generation Co L L C [Member] | |||
Current assets | |||
Cash and cash equivalents | 750 | 416 | |
Restricted cash and cash equivalents | 153 | 138 | |
Accounts receivable, net | |||
Customer | 2,941 | 2,697 | |
Other | 562 | 321 | |
Mark-to-market derivative assets, current | 804 | 976 | |
Receivables from affiliates, current | 173 | 140 | |
Unamortized energy contract assets, current | 49 | 60 | |
Inventories, net | |||
Energy Related Inventory, Other Fossil Fuel | 251 | 264 | |
Materials and supplies | 963 | 937 | |
Assets held for sale | 904 | 0 | |
Other | 883 | 933 | |
Total current assets | 8,433 | 6,882 | |
Property, plant and equipment, net | 23,981 | 24,906 | |
Deferred debits and other assets | |||
Nuclear decommissioning trust funds | 11,661 | 13,272 | |
Investments | 414 | 433 | |
Goodwill | 47 | 47 | |
Mark-to-market derivative assets, noncurrent | 452 | 334 | |
Prepaid pension asset | 1,421 | 1,502 | |
Unamortized energy contract assets, noncurrent | 371 | 395 | |
Deferred income taxes | 21 | 16 | |
Other | 755 | 670 | |
Total deferred debits and other assets | 15,142 | 16,669 | |
Total assets | [2] | 47,556 | 48,457 |
Current liabilities | |||
Short-term borrowings | 0 | 2 | |
Long-term debt due within one year | 906 | 346 | |
Accounts payable | 1,847 | 1,773 | |
Accrued expenses | 898 | 1,022 | |
Payables to affiliates, current | 139 | 123 | |
Borrowings from Exelon intercompany money pool | 100 | 54 | |
Mark-to-market derivative liabilities, current | 449 | 211 | |
Unamortized energy contract liabilities, current | 31 | 43 | |
Renewable energy credit obligation | 343 | 352 | |
Liabilities held for sale | 777 | 0 | |
Other | 279 | 265 | |
Total current liabilities | 5,769 | 4,191 | |
Long-term debt | 6,989 | 7,734 | |
Long-term debt to affiliates | 898 | 910 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 3,383 | 3,811 | |
Asset retirement obligations, noncurrent | 9,450 | 9,844 | |
Non-pension postretirement benefit obligations | 900 | 916 | |
Spent nuclear fuel obligation | 1,171 | 1,147 | |
Payables to affiliates, noncurrent | 2,606 | 3,065 | |
Mark-to-market derivative liabilities, noncurrent | 252 | 174 | |
Unamortized energy contract liabilities, noncurrent | 20 | 48 | |
Other | 610 | 658 | |
Total deferred credits and other liabilities | 18,392 | 19,663 | |
Total liabilities | [2] | 32,048 | 32,498 |
Commitments and Contingencies | |||
Shareholders’ equity | |||
Retained earnings | 3,724 | 4,349 | |
Accumulated other comprehensive income (loss), net | (38) | (37) | |
Member’s equity | |||
Membership interest | 9,518 | 9,357 | |
Total member’s equity | 13,204 | 13,669 | |
Noncontrolling interests | 2,304 | 2,290 | |
Total equity | 15,508 | 15,959 | |
Total liabilities and equity | 47,556 | 48,457 | |
Variable Interest Entity, Consolidated, Assets, Not Pledged | 9,634 | 9,556 | |
Variable Interest Entity, Consolidated, Liabilities, No Recourse | 3,480 | 3,516 | |
Commonwealth Edison Co [Member] | |||
Current assets | |||
Cash and cash equivalents | 135 | 76 | |
Restricted cash and cash equivalents | 29 | 5 | |
Accounts receivable, net | |||
Customer | 539 | 559 | |
Other | 320 | 266 | |
Receivables from affiliates, current | 20 | 13 | |
Inventories, net | |||
Inventories, net | 148 | 152 | |
Regulatory assets, current | 293 | 225 | |
Other | 86 | 68 | |
Total current assets | 1,570 | 1,364 | |
Property, plant and equipment, net | 22,058 | 20,723 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 1,307 | 1,054 | |
Investments | 6 | 6 | |
Goodwill | 2,625 | 2,625 | |
Receivable from affiliates, noncurrent | 2,217 | 2,528 | |
Prepaid pension asset | 1,035 | 1,188 | |
Other | 395 | 238 | |
Total deferred debits and other assets | 7,585 | 7,639 | |
Total assets | 31,213 | 29,726 | |
Current liabilities | |||
Long-term debt due within one year | 300 | 840 | |
Accounts payable | 607 | 568 | |
Accrued expenses | 373 | 327 | |
Payables to affiliates, current | 119 | 74 | |
Regulatory Liability, Current | 293 | 249 | |
Mark-to-market derivative liabilities, current | 26 | 21 | |
Customer deposits | 111 | 112 | |
Other | 96 | 103 | |
Total current liabilities | 1,925 | 2,294 | |
Long-term debt | 7,801 | 6,761 | |
Long-term debt to financing trusts | 205 | 205 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 3,813 | 3,469 | |
Asset retirement obligations, noncurrent | 118 | 111 | |
Non-pension postretirement benefit obligations | 201 | 219 | |
Regulatory liabilities, noncurrent | 6,050 | 6,328 | |
Mark-to-market derivative liabilities, noncurrent | 223 | 235 | |
Other | 630 | 562 | |
Total deferred credits and other liabilities | 11,035 | 10,924 | |
Total liabilities | 20,966 | 20,184 | |
Commitments and Contingencies | |||
Shareholders’ equity | |||
Common stock | 1,588 | 1,588 | |
Other paid-in capital | 7,322 | 6,822 | |
Retained earnings (deficit) unappropriated | (1,639) | (1,639) | |
Retained earnings (deficit) appropriated | 2,976 | 2,771 | |
Total shareholders’ equity | 10,247 | 9,542 | |
Member’s equity | |||
Total liabilities and equity | 31,213 | 29,726 | |
PECO Energy Co [Member] | |||
Current assets | |||
Cash and cash equivalents | 130 | 271 | |
Restricted cash and cash equivalents | 5 | 4 | |
Accounts receivable, net | |||
Customer | 321 | 327 | |
Other | 151 | 105 | |
Inventories, net | |||
Energy Related Inventory, Other Fossil Fuel | 38 | 31 | |
Materials and supplies | 37 | 30 | |
Regulatory assets, current | 81 | 29 | |
Prepaid utility taxes | 0 | 8 | |
Other | 19 | 17 | |
Total current assets | 782 | 822 | |
Property, plant and equipment, net | 8,610 | 8,053 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 460 | 381 | |
Investments | 25 | 25 | |
Receivable from affiliates, noncurrent | 389 | 537 | |
Prepaid pension asset | 349 | 340 | |
Other | 27 | 12 | |
Total deferred debits and other assets | 1,250 | 1,295 | |
Total assets | 10,642 | 10,170 | |
Current liabilities | |||
Long-term debt due within one year | 0 | 500 | |
Accounts payable | 370 | 370 | |
Accrued expenses | 113 | 114 | |
Payables to affiliates, current | 59 | 53 | |
Regulatory Liability, Current | 175 | 141 | |
Customer deposits | 68 | 66 | |
Other | 24 | 23 | |
Total current liabilities | 809 | 1,267 | |
Long-term debt | 3,084 | 2,403 | |
Long-term debt to financing trusts | [3] | 184 | 184 |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 1,933 | 1,789 | |
Asset retirement obligations, noncurrent | 27 | 27 | |
Non-pension postretirement benefit obligations | 288 | 288 | |
Regulatory liabilities, noncurrent | 421 | 549 | |
Other | 76 | 86 | |
Total deferred credits and other liabilities | 2,745 | 2,739 | |
Total liabilities | 6,822 | 6,593 | |
Commitments and Contingencies | |||
Shareholders’ equity | |||
Common stock | 2,578 | 2,489 | |
Retained earnings | 1,242 | 1,087 | |
Accumulated other comprehensive income (loss), net | 0 | 1 | |
Total shareholders’ equity | 3,820 | 3,577 | |
Member’s equity | |||
Total liabilities and equity | 10,642 | 10,170 | |
Baltimore Gas and Electric Company [Member] | |||
Current assets | |||
Cash and cash equivalents | 7 | 17 | |
Restricted cash and cash equivalents | 6 | 1 | |
Accounts receivable, net | |||
Customer | 353 | 375 | |
Other | 90 | 94 | |
Receivables from affiliates, current | 1 | 1 | |
Inventories, net | |||
Materials and supplies | 39 | 40 | |
Gas Held in Storage | 36 | 37 | |
Regulatory assets, current | 177 | 174 | |
Prepaid utility taxes | 74 | 69 | |
Other | 3 | 3 | |
Total current assets | 786 | 811 | |
Property, plant and equipment, net | 8,243 | 7,602 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 398 | 397 | |
Investments | 5 | 5 | |
Prepaid pension asset | 279 | 285 | |
Other | 5 | 4 | |
Total deferred debits and other assets | 687 | 691 | |
Total assets | 9,716 | 9,104 | |
Current liabilities | |||
Short-term borrowings | 35 | 77 | |
Accounts payable | 295 | 265 | |
Accrued expenses | 155 | 164 | |
Payables to affiliates, current | 65 | 52 | |
Regulatory Liability, Current | 77 | 62 | |
Customer deposits | 120 | 116 | |
Other | 27 | 24 | |
Total current liabilities | 774 | 760 | |
Long-term debt | 2,876 | 2,577 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 1,222 | 1,244 | |
Asset retirement obligations, noncurrent | 24 | 23 | |
Non-pension postretirement benefit obligations | 201 | 202 | |
Regulatory liabilities, noncurrent | 1,192 | 1,101 | |
Other | 73 | 56 | |
Total deferred credits and other liabilities | 2,712 | 2,626 | |
Total liabilities | 6,362 | 5,963 | |
Commitments and Contingencies | |||
Shareholders’ equity | |||
Common stock | 1,714 | 1,605 | |
Retained earnings | 1,640 | 1,536 | |
Total shareholders’ equity | 3,354 | 3,141 | |
Member’s equity | |||
Total liabilities and equity | 9,716 | 9,104 | |
Pepco Holdings LLC [Member] | |||
Current assets | |||
Cash and cash equivalents | 124 | 30 | |
Restricted cash and cash equivalents | 43 | 42 | |
Accounts receivable, net | |||
Customer | 453 | 486 | |
Other | 177 | 206 | |
Inventories, net | |||
Materials and supplies | 163 | 151 | |
Gas Held in Storage | 9 | 7 | |
Regulatory assets, current | 489 | 554 | |
Other | 75 | 75 | |
Total current assets | 1,533 | 1,551 | |
Property, plant and equipment, net | 13,446 | 12,498 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 2,312 | 2,493 | |
Investments | 130 | 132 | |
Goodwill | 4,005 | 4,005 | |
Prepaid pension asset | 486 | 490 | |
Deferred income taxes | 12 | 4 | |
Long-term note receivable | 0 | 4 | |
Other | 60 | 70 | |
Total deferred debits and other assets | 7,005 | 7,198 | |
Total assets | [4] | 21,984 | 21,247 |
Current liabilities | |||
Short-term borrowings | 179 | 350 | |
Long-term debt due within one year | 125 | 396 | |
Accounts payable | 496 | 348 | |
Accrued expenses | 256 | 261 | |
Payables to affiliates, current | 94 | 90 | |
Regulatory Liability, Current | 84 | 56 | |
Unamortized energy contract liabilities, current | 119 | 188 | |
Customer deposits | 116 | 119 | |
Other | 123 | 123 | |
Total current liabilities | 1,592 | 1,931 | |
Long-term debt | 6,134 | 5,478 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 2,146 | 2,070 | |
Asset retirement obligations, noncurrent | 52 | 16 | |
Non-pension postretirement benefit obligations | 103 | 105 | |
Regulatory liabilities, noncurrent | 1,864 | 1,872 | |
Unamortized energy contract liabilities, noncurrent | 442 | 561 | |
Other | 369 | 389 | |
Total deferred credits and other liabilities | 4,976 | 5,013 | |
Total liabilities | [4] | 12,702 | 12,422 |
Commitments and Contingencies | |||
Shareholders’ equity | |||
Retained earnings | 62 | (10) | |
Member’s equity | |||
Membership interest | 9,220 | 8,835 | |
Total member’s equity | 9,282 | 8,825 | |
Total equity | 9,282 | 8,825 | |
Total liabilities and equity | 21,984 | 21,247 | |
Variable Interest Entity, Consolidated, Assets, Not Pledged | 33 | 41 | |
Variable Interest Entity, Consolidated, Liabilities, No Recourse | 69 | 102 | |
Potomac Electric Power Company [Member] | |||
Current assets | |||
Cash and cash equivalents | 16 | 5 | |
Restricted cash and cash equivalents | 37 | 35 | |
Accounts receivable, net | |||
Customer | 225 | 250 | |
Other | 81 | 87 | |
Receivables from affiliates, current | 1 | 0 | |
Inventories, net | |||
Inventories, net | 93 | 87 | |
Regulatory assets, current | 270 | 213 | |
Other | 37 | 33 | |
Total current assets | 760 | 710 | |
Property, plant and equipment, net | 6,460 | 6,001 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 643 | 678 | |
Investments | 105 | 102 | |
Prepaid pension asset | 316 | 322 | |
Other | 15 | 19 | |
Total deferred debits and other assets | 1,079 | 1,121 | |
Total assets | 8,299 | 7,832 | |
Current liabilities | |||
Short-term borrowings | 40 | 26 | |
Long-term debt due within one year | 15 | 19 | |
Accounts payable | 214 | 139 | |
Accrued expenses | 126 | 137 | |
Payables to affiliates, current | 62 | 74 | |
Regulatory Liability, Current | 7 | 3 | |
Customer deposits | 54 | 54 | |
Merger related obligation | 38 | 42 | |
Current portion of DC PLUG obligation | 30 | 28 | |
Other | 42 | 28 | |
Total current liabilities | 628 | 550 | |
Long-term debt | 2,704 | 2,521 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 1,064 | 1,063 | |
Non-pension postretirement benefit obligations | 29 | 36 | |
Regulatory liabilities, noncurrent | 822 | 829 | |
Other | 312 | 300 | |
Total deferred credits and other liabilities | 2,227 | 2,228 | |
Total liabilities | 5,559 | 5,299 | |
Commitments and Contingencies | |||
Shareholders’ equity | |||
Common stock | 1,636 | 1,470 | |
Retained earnings | 1,104 | 1,063 | |
Total shareholders’ equity | 2,740 | 2,533 | |
Member’s equity | |||
Total liabilities and equity | 8,299 | 7,832 | |
Delmarva Power & Light Company [Member] | |||
Current assets | |||
Cash and cash equivalents | 23 | 2 | |
Restricted cash and cash equivalents | 1 | 0 | |
Accounts receivable, net | |||
Customer | 134 | 146 | |
Other | 46 | 38 | |
Inventories, net | |||
Materials and supplies | 37 | 36 | |
Gas Held in Storage | 9 | 7 | |
Regulatory assets, current | 59 | 69 | |
Other | 27 | 27 | |
Total current assets | 336 | 325 | |
Property, plant and equipment, net | 3,821 | 3,579 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 231 | 245 | |
Investments | 0 | 0 | |
Goodwill | 8 | 8 | |
Prepaid pension asset | 186 | 193 | |
Other | 6 | 7 | |
Total deferred debits and other assets | 431 | 453 | |
Total assets | 4,588 | 4,357 | |
Current liabilities | |||
Short-term borrowings | 0 | 216 | |
Long-term debt due within one year | 91 | 83 | |
Accounts payable | 111 | 82 | |
Accrued expenses | 39 | 35 | |
Payables to affiliates, current | 33 | 46 | |
Regulatory Liability, Current | 59 | 42 | |
Customer deposits | 35 | 35 | |
Other | 7 | 8 | |
Total current liabilities | 375 | 547 | |
Long-term debt | 1,403 | 1,217 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 628 | 603 | |
Non-pension postretirement benefit obligations | 17 | 14 | |
Regulatory liabilities, noncurrent | 606 | 593 | |
Other | 50 | 48 | |
Total deferred credits and other liabilities | 1,301 | 1,258 | |
Total liabilities | 3,079 | 3,022 | |
Commitments and Contingencies | |||
Shareholders’ equity | |||
Common stock | 914 | 764 | |
Retained earnings | 595 | 571 | |
Total shareholders’ equity | 1,509 | 1,335 | |
Member’s equity | |||
Total liabilities and equity | 4,588 | 4,357 | |
Atlantic City Electric Company [Member] | |||
Current assets | |||
Cash and cash equivalents | 7 | 2 | |
Restricted cash and cash equivalents | 4 | 6 | |
Accounts receivable, net | |||
Customer | 95 | 92 | |
Other | 55 | 56 | |
Receivables from affiliates, current | 1 | 0 | |
Inventories, net | |||
Inventories, net | 33 | 29 | |
Regulatory assets, current | 40 | 71 | |
Other | 5 | 2 | |
Total current assets | 240 | 258 | |
Property, plant and equipment, net | 2,966 | 2,706 | |
Deferred debits and other assets | |||
Regulatory assets, noncurrent | 386 | 359 | |
Investments | 0 | 0 | |
Prepaid pension asset | 67 | 73 | |
Long-term note receivable | 0 | 4 | |
Other | 40 | 45 | |
Total deferred debits and other assets | 493 | 481 | |
Total assets | [5] | 3,699 | 3,445 |
Current liabilities | |||
Short-term borrowings | 139 | 108 | |
Long-term debt due within one year | 18 | 281 | |
Accounts payable | 154 | 118 | |
Accrued expenses | 35 | 33 | |
Payables to affiliates, current | 28 | 29 | |
Regulatory Liability, Current | 18 | 11 | |
Customer deposits | 26 | 31 | |
Other | 4 | 8 | |
Total current liabilities | 422 | 619 | |
Long-term debt | 1,170 | 840 | |
Deferred credits and other liabilities | |||
Deferred income taxes and unamortized investment tax credits | 535 | 493 | |
Non-pension postretirement benefit obligations | 17 | 14 | |
Regulatory liabilities, noncurrent | 402 | 411 | |
Other | 27 | 25 | |
Total deferred credits and other liabilities | 981 | 943 | |
Total liabilities | [5] | 2,573 | 2,402 |
Commitments and Contingencies | |||
Shareholders’ equity | |||
Common stock | 979 | 912 | |
Retained earnings | 147 | 131 | |
Total shareholders’ equity | 1,126 | 1,043 | |
Member’s equity | |||
Total liabilities and equity | 3,699 | 3,445 | |
Variable Interest Entity, Consolidated, Assets, Not Pledged | 23 | 29 | |
Variable Interest Entity, Consolidated, Liabilities, No Recourse | $ 59 | $ 90 | |
[1] | Exelon’s consolidated assets include $9,667 million and $9,597 million at December 31, 2018 and 2017, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,548 million and $3,618 million at December 31, 2018 and 2017, respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 2–Variable Interest Entities for additional information. | ||
[2] | Generation’s consolidated assets include $9,634 million and $9,556 million at December 31, 2018 and 2017, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,480 million and $3,516 million at December 31, 2018 and 2017, respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 2–Variable Interest Entities for additional information. | ||
[3] | Amounts owed to this financing trust are recorded as Long-term debt to financing trusts within PECO’s Consolidated Balance Sheets. | ||
[4] | PHI’s consolidated total assets include $33 million and $41 million at December 31, 2018 and 2017, respectively, of PHI's consolidated VIE that can only be used to settle the liabilities of the VIE. PHI’s consolidated total liabilities include $69 million and $102 million at December 31, 2018 and 2017, respectively, of PHI's consolidated VIE for which the VIE creditors do not have recourse to PHI. See Note 2 - Variable Interest Entities for additional information. | ||
[5] | ACE’s consolidated assets include $23 million and $29 million at December 31, 2018 and 2017, respectively, of ACE’s consolidated VIE that can only be used to settle the liabilities of the VIE. ACE’s consolidated liabilities include $59 million and $90 million at December 31, 2018 and 2017, respectively, of ACE’s consolidated VIE for which the VIE creditors do not have recourse to ACE. See Note 2 - Variable Interest Entities for additional information. |
Consolidated Balance Sheets (Pa
Consolidated Balance Sheets (Parenthetical) - $ / shares $ / shares in Millions | Dec. 31, 2018 | Dec. 31, 2017 |
Statement of Financial Position [Abstract] | ||
Common stock, par value | $ 0 | $ 0 |
Common stock, shares authorized | 2,000,000,000 | 2,000,000,000 |
Common stock, shares outstanding | 968,187,955 | 963,335,888 |
Treasury stock, shares held | 2,000,000 | 2,000,000 |
Consolidated Statement of Chang
Consolidated Statement of Changes in Shareholders Equity - USD ($) shares in Thousands, $ in Millions | Total | Pepco Holdings LLC [Member] | Commitments [Member]Pepco Holdings LLC [Member] | Common Stock [Member] | Treasury Stock [Member] | Retained Earnings [Member] | Accumulated Other Comprehensive Income (Loss) [Member] | Noncontrolling Interest [Member] | Preference Stock Not Subject To Mandatory Redemption [Member] | Exelon Generation Co L L C [Member] | Exelon Generation Co L L C [Member]Membership Interest [Member] | Exelon Generation Co L L C [Member]Undistributed Earnings [Member] | Exelon Generation Co L L C [Member]Accumulated Other Comprehensive Income (Loss) [Member] | Exelon Generation Co L L C [Member]Noncontrolling Interest [Member] | Commonwealth Edison Co [Member] | Commonwealth Edison Co [Member]Common Stock [Member] | Commonwealth Edison Co [Member]Other Additional Capital [Member] | Commonwealth Edison Co [Member]Retained Earnings, Unappropriated [Member] | Commonwealth Edison Co [Member]Retained Earnings Appropriated [Member] | PECO Energy Co [Member] | PECO Energy Co [Member]Common Stock [Member] | PECO Energy Co [Member]Retained Earnings [Member] | PECO Energy Co [Member]Accumulated Other Comprehensive Income (Loss) [Member] | Baltimore Gas and Electric Company [Member] | Baltimore Gas and Electric Company [Member]Parent [Member] | Baltimore Gas and Electric Company [Member]Common Stock [Member] | Baltimore Gas and Electric Company [Member]Common Stock [Member]Parent [Member] | Baltimore Gas and Electric Company [Member]Retained Earnings [Member] | Baltimore Gas and Electric Company [Member]Membership Interest [Member] | Baltimore Gas and Electric Company [Member]Membership Interest [Member]Parent [Member] | Baltimore Gas and Electric Company [Member]Preference Stock Not Subject To Mandatory Redemption [Member] | Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member]Pepco Holdings LLC [Member] | [4] | Pepco Holdings LLC [Member]Deferred Compensation, Share-based Payments [Member]Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member]Common Stock [Member] | [1] | Pepco Holdings LLC [Member]Retained Earnings [Member] | Pepco Holdings LLC [Member]Membership Interest [Member] | Pepco Holdings LLC [Member]Membership Interest [Member]Pepco Holdings LLC [Member] | [4] | Pepco Holdings LLC [Member]Undistributed Earnings [Member] | Pepco Holdings LLC [Member]Accumulated Other Comprehensive Income (Loss) [Member] | Pepco Holdings LLC [Member]Additional Paid-in Capital [Member] | Potomac Electric Power Company [Member] | Potomac Electric Power Company [Member]Common Stock [Member] | Potomac Electric Power Company [Member]Retained Earnings [Member] | Delmarva Power & Light Company [Member] | Delmarva Power & Light Company [Member]Common Stock [Member] | Delmarva Power & Light Company [Member]Retained Earnings [Member] | Atlantic City Electric Company [Member] | Atlantic City Electric Company [Member]Common Stock [Member] | Atlantic City Electric Company [Member]Retained Earnings [Member] | ||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest | $ 27,330 | $ 18,676 | $ (2,327) | $ 12,104 | $ (2,624) | $ 1,308 | $ 193 | ||||||||||||||||||||||||||||||||||||||||||||||||||
Other Additional Capital | Successor [Member] | $ 3,829 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Beginning Balance (in shares) at Dec. 31, 2015 | 954,668 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2015 | $ 8,243 | $ 1,588 | $ 5,677 | $ (1,639) | $ 2,617 | $ 3,236 | $ 2,455 | $ 780 | $ 1 | $ 2,877 | $ 1,367 | $ 1,320 | $ 2,687 | $ 190 | $ 2,240 | $ 1,122 | $ 1,118 | $ 1,237 | $ 612 | $ 625 | $ 1,000 | $ 773 | $ 227 | ||||||||||||||||||||||||||||||||||
Beginning Balance (Predecessor [Member]) at Dec. 31, 2015 | $ 4,413 | $ 3,832 | $ 617 | $ (36) | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2015 | $ 12,978 | $ 8,997 | $ 2,737 | $ (63) | $ 1,307 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Net income (loss) | Predecessor [Member] | 19 | 19 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Employee stock purchase plan issuances | Predecessor [Member] | 3 | 3 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Tax benefit on stock compensation | Predecessor [Member] | (1) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | Predecessor [Member] | 1 | 1 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance (Predecessor [Member]) at Mar. 23, 2016 | 4,439 | 3,838 | 636 | (35) | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stockholders' Equity, Other | Predecessor [Member] | 3 | 3 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Beginning Balance (in shares) at Dec. 31, 2015 | 954,668 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2015 | 8,243 | 1,588 | 5,677 | (1,639) | 2,617 | 3,236 | 2,455 | 780 | 1 | 2,877 | 1,367 | 1,320 | 2,687 | 190 | 2,240 | 1,122 | 1,118 | 1,237 | 612 | 625 | 1,000 | 773 | 227 | ||||||||||||||||||||||||||||||||||
Beginning Balance (Predecessor [Member]) at Dec. 31, 2015 | 4,413 | 3,832 | 617 | (36) | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Beginning Balance at Dec. 31, 2015 | 12,978 | 8,997 | 2,737 | (63) | 1,307 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Net income (loss) | $ 1,196 | $ (66) | 1,121 | 67 | 8 | 550 | 483 | 67 | 378 | 378 | 438 | 438 | 294 | 294 | 294 | 42 | 42 | (9) | (9) | (42) | 0 | (42) | |||||||||||||||||||||||||||||||||||
Stock Issued During Period, Shares, Share-based Compensation, Gross | 2,868 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stock Issued During Period, Value, Share-based Compensation, Gross | $ 85 | 85 | 0 | 0 | 0 | 0 | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||
Employee stock purchase plan issuances, shares | 1,242 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Employee stock purchase plan issuances | $ 55 | 55 | 0 | 0 | 0 | 0 | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||
Tax benefit on stock compensation | (18) | (18) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Noncontrolling Interest, Decrease from Distributions to Noncontrolling Interest Holders | 5 | 5 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Sale of noncontrolling interests | 239 | (4) | 243 | 239 | (4) | 243 | |||||||||||||||||||||||||||||||||||||||||||||||||||
Noncontrolling Interest, Change in Redemption Value | 157 | 157 | 157 | 157 | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Noncontrolling Interest, Period Increase (Decrease) | 5 | 5 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Common stock dividends | (1,172) | (1,172) | (369) | (369) | (277) | (277) | (179) | (179) | (179) | (169) | (169) | (54) | (54) | (63) | 0 | (63) | |||||||||||||||||||||||||||||||||||||||||
Preferred and preference stock dividends | (8) | (8) | (8) | (8) | (8) | ||||||||||||||||||||||||||||||||||||||||||||||||||||
Stock Redeemed or Called During Period, Value | (193) | (193) | (190) | (190) | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Adjustments to Additional Paid in Capital, Other | 268 | 268 | 315 | 315 | 61 | $ (7) | 61 | $ (7) | 61 | $ (7) | 187 | 187 | 152 | 152 | 139 | 139 | |||||||||||||||||||||||||||||||||||||||||
Distribution Made to Limited Liability Company (LLC) Member, Cash Distributions Declared | (922) | (922) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Effects Allocated Directly to Equity, Other | 18 | 18 | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | $ (36) | 0 | (36) | 9 | 9 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance (in shares) at Dec. 31, 2016 | 958,778 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance at Dec. 31, 2016 | 8,725 | 1,588 | 6,150 | (1,639) | 2,626 | 3,415 | 2,473 | 941 | 1 | 2,848 | 1,421 | 1,427 | 2,848 | 0 | 2,300 | 1,309 | 991 | 1,326 | 764 | 562 | 1,034 | 912 | 122 | ||||||||||||||||||||||||||||||||||
Ending Balance (Successor [Member]) at Dec. 31, 2016 | 8,016 | $ 8,077 | $ (61) | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance at Dec. 31, 2016 | 13,284 | 9,261 | 2,298 | (54) | 1,779 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Additional Capital | Successor [Member] | 3,835 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Common stock | Successor [Member] | $ 3 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Beginning Balance (Predecessor [Member]) at Mar. 23, 2016 | 4,439 | $ 3,838 | $ 636 | (35) | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Net income (loss) | Successor [Member] | (61) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | Successor [Member] | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance (in shares) at Dec. 31, 2016 | 958,778 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance at Dec. 31, 2016 | 8,725 | 1,588 | 6,150 | (1,639) | 2,626 | 3,415 | 2,473 | 941 | 1 | 2,848 | 1,421 | 1,427 | 2,848 | 0 | 2,300 | 1,309 | 991 | 1,326 | 764 | 562 | 1,034 | 912 | 122 | ||||||||||||||||||||||||||||||||||
Ending Balance (Successor [Member]) at Dec. 31, 2016 | 8,016 | 8,077 | (61) | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance at Dec. 31, 2016 | 13,284 | 9,261 | 2,298 | (54) | 1,779 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stockholders' Equity, Other | Successor [Member] | $ 33 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stockholders' Equity, Other | $ 29 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Common stock | Successor [Member] | 165 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Business Combination, Contingent Consideration, Asset | Successor [Member] | 235 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Business Combination, Contingent Consideration, Asset | $ 235 | 163 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Beginning Balance (Successor [Member]) at Mar. 24, 2016 | [2] | 7,200 | 7,200 | 0 | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Net income (loss) | Successor [Member] | (61) | (61) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Distribution Made to Limited Liability Company (LLC) Member, Cash Distributions Paid | Successor [Member] | 53 | 53 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Distribution Made to Limited Liability Company (LLC) Member, Cash Distributions Declared | Successor [Member] | [3] | (400) | (400) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
Members Equity Including Portion Attributable To Noncontrolling Interest Acquisitions | Successor [Member] | 1,251 | 1,251 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance (in shares) at Dec. 31, 2016 | 958,778 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance at Dec. 31, 2016 | 8,725 | 1,588 | 6,150 | (1,639) | 2,626 | 3,415 | 2,473 | 941 | 1 | 2,848 | 1,421 | 1,427 | 2,848 | 0 | 2,300 | 1,309 | 991 | 1,326 | 764 | 562 | 1,034 | 912 | 122 | ||||||||||||||||||||||||||||||||||
Ending Balance (Successor [Member]) at Dec. 31, 2016 | 8,016 | 8,077 | (61) | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance at Dec. 31, 2016 | 13,284 | 9,261 | 2,298 | (54) | 1,779 | ||||||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stockholders' Equity, Other | Successor [Member] | 35 | $ (62) | 35 | $ (62) | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest | $ 27,640 | 18,794 | (2,327) | 12,053 | (2,660) | [5] | 1,780 | 0 | (54) | [5] | 1 | [5] | |||||||||||||||||||||||||||||||||||||||||||||
Other Additional Capital | 158 | 158 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Retained Earnings, Appropriated | (378) | 378 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Net income (loss) | $ 3,876 | 364 | 3,786 | 90 | 0 | 2,798 | 2,710 | 88 | 567 | 567 | 434 | 434 | 307 | 307 | 307 | 362 | 362 | 205 | 205 | 121 | 121 | 77 | 0 | 77 | |||||||||||||||||||||||||||||||||
Stock Issued During Period, Shares, Share-based Compensation, Gross | 5,066 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stock Issued During Period, Value, Share-based Compensation, Gross | $ 56 | 56 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||||
Employee stock purchase plan issuances, shares | 1,324 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Employee stock purchase plan issuances | $ 150 | 150 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||||
Stock Issued During Period, Shares, New Issues | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stock Issued During Period, Value, New Issues | $ 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stock Issued During Period, Value, Treasury Stock Reissued | (1,150) | 2,204 | (1,054) | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
Tax benefit on stock compensation | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Sale of noncontrolling interests | 407 | (36) | 443 | 407 | (36) | 443 | |||||||||||||||||||||||||||||||||||||||||||||||||||
Noncontrolling Interest, Change in Redemption Value | (20) | (20) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Noncontrolling Interest, Period Increase (Decrease) | (18) | (18) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Distribution Made to Limited Liability Company (LLC) Member, Cash Distributions Paid | 33 | 33 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Common stock dividends | (1,243) | (1,243) | (422) | (422) | (288) | (288) | (198) | (198) | (198) | (133) | (133) | (112) | (112) | (68) | 0 | (68) | |||||||||||||||||||||||||||||||||||||||||
Adjustments to Additional Paid in Capital, Other | 0 | 99 | 99 | 651 | 651 | 184 | 184 | 184 | 0 | 161 | 161 | ||||||||||||||||||||||||||||||||||||||||||||||
Distribution Made to Limited Liability Company (LLC) Member, Cash Distributions Declared | (659) | (659) | (311) | (311) | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Effects Allocated Directly to Equity, Other | 0 | 16 | 16 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | $ 171 | 0 | 173 | [5] | (2) | 15 | 17 | [5] | (2) | 0 | [5] | 0 | |||||||||||||||||||||||||||||||||||||||||||||
Members Equity Including Portion Attributable To Noncontrolling Interest Acquisitions | 758 | 758 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | 539 | (539) | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance (in shares) at Dec. 31, 2017 | 965,168 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance at Dec. 31, 2017 | $ 29,896 | 9,542 | 1,588 | 6,822 | (1,639) | 2,771 | 3,577 | 2,489 | 1,087 | 1 | 3,141 | 1,605 | 1,536 | 3,141 | 0 | 2,533 | 1,470 | 1,063 | 1,335 | 764 | 571 | 1,043 | 912 | 131 | |||||||||||||||||||||||||||||||||
Ending Balance at Dec. 31, 2017 | 15,959 | 9,357 | 4,349 | (37) | 2,290 | 8,825 | 8,835 | (10) | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest | 32,187 | 18,964 | (123) | 14,081 | (3,026) | [5] | 2,291 | 0 | (37) | [5] | 1 | [5] | |||||||||||||||||||||||||||||||||||||||||||||
Other Additional Capital | 21 | 21 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Retained Earnings, Appropriated | 2,771 | (567) | 567 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
Additional Paid in Capital | 6,822 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Common stock | 18,964 | 1,588 | 2,489 | 1,605 | 1,470 | 764 | 912 | ||||||||||||||||||||||||||||||||||||||||||||||||||
Net income (loss) | $ 2,084 | $ 453 | 2,010 | 74 | 0 | 443 | 370 | 73 | 664 | 664 | 460 | 460 | 313 | 313 | 313 | 398 | 398 | 210 | 210 | 120 | 120 | 75 | 0 | 75 | |||||||||||||||||||||||||||||||||
Stock Issued During Period, Shares, Share-based Compensation, Gross | 3,534 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stock Issued During Period, Value, Share-based Compensation, Gross | $ 41 | 41 | 0 | 0 | 0 | 0 | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||
Employee stock purchase plan issuances, shares | 1,318 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Employee stock purchase plan issuances | $ 105 | 105 | 0 | 0 | 0 | 0 | 0 | ||||||||||||||||||||||||||||||||||||||||||||||||||
Sale of noncontrolling interests | 6 | 6 | 0 | 0 | 0 | 6 | 6 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
Noncontrolling Interest, Period Increase (Decrease) | (60) | 0 | (60) | (60) | (60) | ||||||||||||||||||||||||||||||||||||||||||||||||||||
Common stock dividends | (1,339) | (1,339) | (459) | (459) | (306) | (306) | (209) | (209) | (209) | (169) | (169) | (96) | (96) | (59) | 0 | (59) | |||||||||||||||||||||||||||||||||||||||||
Adjustments to Additional Paid in Capital, Other | 155 | 155 | 500 | 500 | 109 | 109 | 0 | 109 | 0 | 166 | 166 | 150 | 150 | 67 | 67 | ||||||||||||||||||||||||||||||||||||||||||
Distribution Made to Limited Liability Company (LLC) Member, Cash Distributions Declared | (1,001) | (1,001) | (326) | (326) | |||||||||||||||||||||||||||||||||||||||||||||||||||||
Income Tax Effects Allocated Directly to Equity, Other | 0 | 89 | 89 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other comprehensive income (loss), net of income taxes | 42 | 0 | 41 | [5] | 1 | 3 | 2 | [5] | 1 | 0 | [5] | 0 | |||||||||||||||||||||||||||||||||||||||||||||
Members Equity Including Portion Attributable To Noncontrolling Interest Acquisitions | 385 | 385 | |||||||||||||||||||||||||||||||||||||||||||||||||||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | $ 4 | 14 | (10) | 3 | 6 | (3) | |||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance (in shares) at Dec. 31, 2018 | 970,020 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Ending Balance at Dec. 31, 2018 | $ 30,764 | 10,247 | $ 1,588 | $ 7,322 | (1,639) | 2,976 | 3,820 | $ 2,578 | $ 1,242 | 0 | 3,354 | $ 1,714 | $ 1,640 | $ 3,354 | $ 0 | 2,740 | $ 1,636 | $ 1,104 | 1,509 | $ 914 | $ 595 | 1,126 | $ 979 | $ 147 | |||||||||||||||||||||||||||||||||
Ending Balance at Dec. 31, 2018 | $ 15,508 | $ 9,518 | $ 3,724 | (38) | $ 2,304 | $ 9,282 | $ 9,220 | $ 62 | $ 0 | ||||||||||||||||||||||||||||||||||||||||||||||||
Increase (Decrease) in Stockholders' Equity [Roll Forward] | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Stockholders' Equity, Including Portion Attributable to Noncontrolling Interest | 33,070 | $ 19,116 | $ (123) | $ 14,766 | $ (2,995) | [5] | $ 2,306 | $ 0 | $ (38) | [5] | $ 0 | [5] | |||||||||||||||||||||||||||||||||||||||||||||
Retained Earnings, Appropriated | 2,976 | $ (664) | $ 664 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
Additional Paid in Capital | 7,322 | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Common stock | $ 19,116 | $ 1,588 | $ 2,578 | $ 1,714 | $ 1,636 | $ 914 | $ 979 | ||||||||||||||||||||||||||||||||||||||||||||||||||
[1] | At March 23, 2016 and December 31, 2015, PHI's (predecessor) shareholders' equity included $3,835 million and $3,829 million of other paid-in capital, and $3 million and $3 million of common stock, respectively. | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
[2] | The March 24, 2016, beginning balance differs from the PHI Merger total purchase price by $59 million related to an acquisition accounting adjustment recorded at Exelon Corporate to reflect unitary state income tax consequences of the merger. | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
[3] | Distribution to member includes $235 million of net assets associated with PHI's unregulated business interests and $165 million of cash, each of which were distributed by PHI to Exelon. | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
[4] | he liabilities assumed include $29 million for PHI stock-based compensation awards and $33 million for a merger related obligation, each assumed by PHI from Exelon. See Note 5 — Mergers, Acquisitions and Dispositions. | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
[5] | All amounts are net of tax and noncontrolling interests. Amounts in parenthesis represent a decrease in AOCI. |
Consolidated Statement of Cha_2
Consolidated Statement of Changes in Shareholders Equity (Parenthetical) - $ / shares | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Statement of Stockholders' Equity [Abstract] | |||
Common Stock, Dividends, Per Share, Declared | $ 1.38 | $ 1.31 | $ 1.26 |
Significant Accounting Policies
Significant Accounting Policies | 12 Months Ended |
Dec. 31, 2018 | |
Accounting Policies [Abstract] | |
Significant Accounting Policies (All Registrants) | Significant Accounting Policies (All Registrants) Description of Business (All Registrants) Exelon is a utility services holding company engaged in the generation, delivery and marketing of energy through Generation and the energy distribution and transmission businesses through ComEd, PECO, BGE, Pepco, DPL and ACE. On March 23, 2016 , Exelon completed the merger with PHI, which became a wholly owned subsidiary of Exelon. PHI is a utility services holding company engaged through its principal wholly owned subsidiaries, Pepco, DPL and ACE, in the energy distribution and transmission businesses. See Note 5 — Mergers, Acquisitions and Dispositions for additional information regarding the merger transaction. Name of Registrant Business Service Territories Exelon Generation Generation, physical delivery and marketing of power across multiple geographical regions through its customer-facing business, Constellation, which sells electricity to both wholesale and retail customers. Generation also sells natural gas, renewable energy and other energy-related products and services. Six reportable segments: Mid-Atlantic, Midwest, New England, New York, ERCOT and Other Power Regions Commonwealth Edison Company Purchase and regulated retail sale of electricity Northern Illinois, including the City of Chicago Transmission and distribution of electricity to retail customers PECO Energy Company Purchase and regulated retail sale of electricity and natural gas Southeastern Pennsylvania, including the City of Philadelphia (electricity) Transmission and distribution of electricity and distribution of natural gas to retail customers Pennsylvania counties surrounding the City of Philadelphia (natural gas) Baltimore Gas and Electric Company Purchase and regulated retail sale of electricity and natural gas Central Maryland, including the City of Baltimore (electricity and natural gas) Transmission and distribution of electricity and distribution of natural gas to retail customers Pepco Holdings LLC Utility services holding company engaged, through its reportable segments Pepco, DPL and ACE Service Territories of Pepco, DPL and ACE Potomac Electric Purchase and regulated retail sale of electricity District of Columbia, and major portions of Montgomery and Prince George’s Counties, Maryland. Transmission and distribution of electricity to retail customers Delmarva Power & Light Company Purchase and regulated retail sale of electricity and natural gas Portions of Delaware and Maryland (electricity) Transmission and distribution of electricity and distribution of natural gas to retail customers Portions of New Castle County, Delaware (natural gas) Atlantic City Electric Company Purchase and regulated retail sale of electricity Portions of Southern New Jersey Transmission and distribution of electricity to retail customers Basis of Presentation (All Registrants) This is a combined annual report of all Registrants. The Notes to the Consolidated Financial Statements apply to the Registrants as indicated above in the Index to Combined Notes to Consolidated Financial Statements and parenthetically next to each corresponding disclosure. When appropriate, the Registrants are named specifically for their related activities and disclosures. Each of the Registrant’s Consolidated Financial Statements includes the accounts of its subsidiaries. All intercompany transactions have been eliminated. As a result of the merger with PHI, Exelon’s financial reporting reflects PHI’s consolidated financial results subsequent to the March 23, 2016 , acquisition date. Exelon has accounted for the merger transaction applying the acquisition method of accounting, which it has pushed-down to the consolidated financial statements of PHI such that the assets and liabilities of PHI are recorded at their respective fair values, and goodwill has been established as of the acquisition date. Accordingly, the consolidated financial statements of PHI for periods before and after the March 23, 2016 , acquisition date reflect different bases of accounting, and the results of operations and the financial positions of the predecessor and successor periods are not comparable. The acquisition method of accounting has not been pushed down to PHI’s wholly owned subsidiary utility registrants, Pepco, DPL and ACE. For financial statement purposes, beginning on March 24, 2016 , disclosures related to Exelon also apply to PHI, Pepco, DPL and ACE, unless otherwise noted. Through its business services subsidiary, BSC, Exelon provides its subsidiaries with a variety of support services at cost, including legal, human resources, financial, information technology and supply management services. PHI also has a business services subsidiary, PHISCO, which provides a variety of support services at cost, including legal, accounting, engineering, customer operations, distribution and transmission planning, asset management, system operations, and power procurement, to PHI operating companies. The costs of BSC and PHISCO are directly charged or allocated to the applicable subsidiaries. The results of Exelon’s corporate operations are presented as “Other” within the consolidated financial statements and include intercompany eliminations unless otherwise disclosed. Exelon owns 100% of Generation, PECO, BGE and PHI and more than 99% of ComEd. PHI owns 100% of Pepco, DPL and ACE. Generation owns 100% of its significant consolidated subsidiaries, either directly or indirectly, except for certain consolidated VIEs, including CENG and EGRP, of which Generation holds a 50.01% and 51% interest, respectively. The remaining interests in these consolidated VIEs are included in noncontrolling interests on Exelon’s and Generation’s Consolidated Balance Sheets. See Note 2 — Variable Interest Entities for additional information of Exelon’s and Generation’s consolidated VIEs. The Registrants consolidate the accounts of entities in which a Registrant has a controlling financial interest, after the elimination of intercompany transactions. Where the Registrants do not have a controlling financial interest in an entity, proportionate consolidation, equity method accounting or accounting for investments in equity securities without readily determinable fair value is applied. The Registrants apply proportionate consolidation when they have an undivided interest in an asset and are proportionately liable for their share of each liability associated with the asset. The Registrants proportionately consolidate their undivided ownership interests in jointly owned electric plants and transmission facilities. Under proportionate consolidation, the Registrants separately record their proportionate share of the assets, liabilities, revenues and expenses related to the undivided interest in the asset. The Registrants apply equity method accounting when they have significant influence over an investee through an ownership in common stock, which generally approximates a 20% to 50% voting interest. The Registrants apply equity method accounting to certain investments and joint ventures, including certain financing trusts of ComEd and PECO. Under equity method accounting, the Registrants report their interest in the entity as an investment and the Registrants’ percentage share of the earnings from the entity as single line items in their financial statements. The Registrants use accounting for investments in equity securities without readily determinable fair values if they lack significant influence, which generally results when they hold less than 20% of the common stock of an entity. Under accounting for investments in equity securities without readily determinable fair values, the Registrants report their investments at cost adjusted for changes from observable transactions for identical or similar investments of the same issuer, less impairment. Changes in measurement are reported in earnings. The accompanying consolidated financial statements have been prepared in accordance with GAAP for annual financial statements and in accordance with the instructions to Form 10-K and Regulation S-X promulgated by the SEC. Use of Estimates (All Registrants) The preparation of financial statements of each of the Registrants in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Areas in which significant estimates have been made include, but are not limited to, the accounting for nuclear decommissioning costs and other AROs, pension and other postretirement benefits, the application of purchase accounting, inventory reserves, allowance for uncollectible accounts, goodwill and asset impairments, derivative instruments, unamortized energy contracts, fixed asset depreciation, environmental costs and other loss contingencies, taxes and unbilled energy revenues. Actual results could differ from those estimates. Prior Period Adjustments and Reclassifications (All Registrants) Certain prior year amounts in the Registrants' Consolidated Statements of Operations and Comprehensive Incom e, Consolidated Statements of Cash Flows, Consolidated Balance Sheets and Consolidated Statements of Changes in Shareholders' Equity have been recasted to reflect new accounting standards issued by the FASB and adopted as of January 1, 2018. See New Accounting Standards below for additional information. Accounting for the Effects of Regulation (Exelon and the Utility Registrants) For their regulated electric and gas operations, Exelon and the Utility Registrants reflect the effects of cost-based rate regulation in their financial statements, which is required for entities with regulated operations that meet the following criteria: 1) rates are established or approved by a third-party regulator; (2) rates are designed to recover the entities’ cost of providing services or products; and (3) there is a reasonable expectation that rates designed to recover costs can be charged to and collected from customers. Exelon and the Utility Registrants account for their regulated operations in accordance with regulatory and legislative guidance from the regulatory authorities having jurisdiction, principally the ICC, PAPUC, MDPSC, DCPSC, DPSC and NJBPU, under state public utility laws and the FERC under various Federal laws. Regulatory assets and liabilities are amortized and the related expense or revenue is recognized in the Consolidated Statements of Operations consistent with the recovery or refund included in customer rates. Exelon's regulatory assets and liabilities as of the balance sheet date are probable of being recovered or settled in future rates. If a separable portion of the Registrants' business was no longer able to meet the criteria discussed above, the affected entities would be required to eliminate from their consolidated financial statements the effects of regulation for that portion, which could have a material impact on their financial statements. See Note 4 — Regulatory Matters for additional information. With the exception of income tax-related regulatory assets and liabilities, Exelon and the Utility Registrants classify regulatory assets and liabilities with a recovery or settlement period greater than one year as both current and non-current in their Consolidated Balance Sheets, with the current portion representing the amount expected to be recovered from or settled to customers over the next twelve-month period as of the balance sheet date. Income tax-related regulatory assets and liabilities are classified entirely as non-current in Exelon's and the Utility Registrants’ Consolidated Balance Sheets to align with the classification of the related deferred income tax balances. Exelon and the Utility Registrants treat the impacts of a final rate order received after the balance sheet date but prior to the issuance of the financial statements as a non-recognized subsequent event, as the receipt of a final rate order is a separate and distinct event that has future impacts on the parties affected by the order. Revenues (All Registrants) Operating Revenues. The Registrants’ operating revenues generally consist of revenues from contracts with customers involving the sale and delivery of energy commodities and related products and services, utility revenues from alternative revenue programs (ARP), and realized and unrealized revenues recognized under mark-to-market energy commodity derivative contracts. The Registrants recognize revenue from contracts with customers to depict the transfer of goods or services to customers in an amount that the entities expect to be entitled to in exchange for those goods or services. Generation’s primary sources of revenue include competitive sales of power, natural gas, and other energy-related products and services. The Utility Registrants’ primary sources of revenue include regulated electric and natural gas tariff sales, distribution and transmission services. At the end of each month, the Registrants accrue an estimate for the unbilled amount of energy delivered or services provided to customers. ComEd records ARP revenue for its best estimate of the electric distribution, energy efficiency, and transmission revenue impacts resulting from future changes in rates that ComEd believes are probable of approval by the ICC and FERC in accordance with its formula rate mechanisms. BGE, Pepco and DPL record ARP revenue for their best estimate of the electric and natural gas distribution revenue impacts resulting from future changes in rates that they believe are probable of approval by the MDPSC and/or DCPSC in accordance with their revenue decoupling mechanisms. PECO, BGE, Pepco, DPL and ACE record ARP revenue for their best estimate of the transmission revenue impacts resulting from future changes in rates that they believe are probable of approval by FERC in accordance with their formula rate mechanisms. See Note 4 — Regulatory Matters and Note 23 — Supplemental Financial Information for additional information. Option Contracts, Swaps and Commodity Derivatives. Certain option contracts and swap arrangements that meet the definition of derivative instruments are recorded at fair value with subsequent changes in fair value recognized as revenue or expense. The classification of revenue or expense is based on the intent of the transaction. To the extent a Utility Registrant receives full cost recovery for energy procurement and related costs from retail customers, it records the fair value of its energy swap contracts with unaffiliated suppliers as well as an offsetting regulatory asset or liability in its Consolidated Balance Sheets. See Note 4 — Regulatory Matters and Note 12 — Derivative Financial Instruments for additional information. Taxes Directly Imposed on Revenue-Producing Transactions. The Registrants collect certain taxes from customers such as sales and gross receipts taxes, along with other taxes, surcharges and fees, that are levied by state or local governments on the sale or distribution of gas and electricity. Some of these taxes are imposed on the customer, but paid by the Registrants, while others are imposed on the Registrants. Where these taxes are imposed on the customer, such as sales taxes, they are reported on a net basis with no impact to the Consolidated Statements of Operations and Comprehensive Income. However, where these taxes are imposed on the Registrants, such as gross receipts taxes or other surcharges or fees, they are reported on a gross basis. Accordingly, revenues are recognized for the taxes collected from customers along with an offsetting expense. Se e Note 23 — Supplemental Financial Information for Generation’s, ComEd’s, PECO’s, BGE’s, Pepco's, DPL's and ACE's utility taxes that are presented on a gross basis. Income Taxes (All Registrants) Deferred Federal and state income taxes are recorded on significant temporary differences between the book and tax basis of assets and liabilities and for tax benefits carried forward. Investment tax credits have been deferred in the Registrants’ Consolidated Balance Sheets and are recognized in book income over the life of the related property. The Registrants account for uncertain income tax positions using a benefit recognition model with a two-step approach; a more-likely-than-not recognition criterion; and a measurement approach that measures the position as the largest amount of tax benefit that is greater than 50% likely of being realized upon ultimate settlement. If it is not more-likely-than-not that the benefit of the tax position will be sustained on its technical merits, no benefit is recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold. The Registrants recognize accrued interest related to unrecognized tax benefits in Interest expense or Other income and deductions (interest income) and recognize penalties related to unrecognized tax benefits in Other, net in their Consolidated Statements of Operations and Comprehensive Income. Pursuant to the IRC and relevant state taxing authorities, Exelon and its subsidiaries file consolidated or combined income tax returns for Federal and certain state jurisdictions where allowed or required. See Note 14 — Income Taxes for additional information. Cash and Cash Equivalents (All Registrants) The Registrants consider investments purchased with an original maturity of three months or less to be cash equivalents. Restricted Cash and Cash Equivalents (All Registrants) Restricted cash and cash equivalents represent funds that are restricted to satisfy designated current liabilities. As of December 31, 2018 and 2017 , the Registrants' restricted cash and cash equivalents primarily represented the following items: Registrant Description Exelon Payment of medical, dental, vision and long-term disability benefits, in addition to the items listed for Generation and the Utility Registrants. Generation Project-specific nonrecourse financing structures for debt service and financing of operations of the underlying entities. ComEd Collateral held from suppliers associated with energy and REC procurement contracts, any over-recovered RPS costs and alternative compliance payments received from RES pursuant to FEJA and costs for the remediation of an MGP site. PECO Proceeds from the sales of assets that were subject to PECO’s mortgage indenture. BGE Proceeds from the loan program for the completion of certain energy efficiency measures and collateral held from energy suppliers. PHI Payment of merger commitments, collateral held from its energy suppliers associated with procurement contracts and repayment of transition bonds. Pepco Payment of merger commitments and collateral held from energy suppliers. DPL Collateral held from energy suppliers. ACE Repayment of transition bonds and collateral held from energy suppliers. Restricted cash and cash equivalents not available to satisfy current liabilities are classified as noncurrent assets. As of December 31, 2018 and 2017 , the Registrants' noncurrent restricted cash and cash equivalents primarily represented ComEd’s over-recovered RPS costs and alternative compliance payments received from RES pursuant to FEJA and costs for the remediation of an MGP site, and ACE’s repayment of transition bonds. See Note 23 — Supplemental Financial Information for additional information. Allowance for Uncollectible Accounts (All Registrants) The allowance for uncollectible accounts reflects the Registrants’ best estimates of losses on the customers' accounts receivable balances. For Generation, the allowance is based on accounts receivable aging historical experience and other currently available information. Utility Registrants estimate the allowance by applying loss rates developed specifically for each company to the outstanding receivable balance by customer risk segment. Utility Registrants' customer accounts are written off consistent with approved regulatory requirements. See Note 4 — Regulatory Matters for additional information regarding the regulatory recovery of uncollectible accounts receivable at ComEd and ACE. Variable Interest Entities (All Registrants) Exelon accounts for its investments in and arrangements with VIEs based on the following specific requirements: • requires an entity to qualitatively assess whether it should consolidate a VIE based on whether the entity has a controlling financial interest, • requires an ongoing reconsideration of this assessment instead of only upon certain triggering events, and • requires the entity that consolidates a VIE (the primary beneficiary) to disclose (1) the assets of the consolidated VIE, if they can be used to only settle specific obligations of the consolidated VIE, and (2) the liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary. See Note 2 — Variable Interest Entities for additional information. Inventories (All Registrants) Inventory is recorded at the lower of weighted average cost or net realizable value. Provisions are recorded for excess and obsolete inventory. Fossil fuel, materials and supplies, and emissions allowances are generally included in inventory when purchased. Fossil fuel and emissions allowances are expensed to purchased power and fuel expense when used or sold. Materials and supplies generally includes transmission, distribution and generating plant materials and are expensed to operating and maintenance or capitalized to property, plant and equipment, as appropriate, when installed or used. Debt and Equity Security Investments (Exelon and Generation ) Debt Security Investments. Debt securities are reported at fair value and classified as available-for-sale securities. Unrealized gains and losses, net of tax, are reported in OCI. Equity Security Investments without Readily Determinable Fair Values. Exelon has certain equity securities without readily determinable fair values. Exelon has elected to use the practicability exception to measure these investments, defined as cost adjusted for changes from observable transactions for identical or similar investments of the same issuer, less impairment. Changes in measurement are reported in earnings. Equity Security Investments with Readily Determinable Fair Values. Equity securities held in the NDT funds are classified as equity securities with readily determinable fair values. Realized and unrealized gains and losses, net of tax, on Generation’s NDT funds associated with the Regulatory Agreement Units are included in regulatory liabilities at Exelon, ComEd and PECO and in Noncurrent payables to affiliates at Generation and in Noncurrent receivables from affiliates at ComEd and PECO. Realized and unrealized gains and losses, net of tax, on Generation’s NDT funds associated with the Non-Regulatory Agreement Units are included in earnings at Exelon and Generation. Exelon's and Generation's NDT funds are classified as current or noncurrent assets, depending on the timing of the decommissioning activities and income taxes on trust earnings. See Note 4 — Regulatory Matters for additional information regarding ComEd’s and PECO’s regulatory assets and liabilities and Note 11 — Fair Value of Financial Assets and Liabilities and Note 15 — Asset Retirement Obligations for additional information regarding marketable securities held by NDT funds. Property, Plant and Equipment (All Registrants) Property, plant and equipment is recorded at original cost. Original cost includes construction-related direct labor and material costs. The Utility Registrants also include indirect construction costs including labor and related costs of departments associated with supporting construction activities. When appropriate, original cost also includes capitalized interest for Generation, Exelon Corporate and PHI and AFUDC for regulated property at the Utility Registrants. The cost of repairs and maintenance, including planned major maintenance activities and minor replacements of property, is charged to Operating and maintenance expense as incurred. Third parties reimburse the Utility Registrants for all or a portion of expenditures for certain capital projects. Such contributions in aid of construction costs (CIAC) are recorded as a reduction to Property, plant and equipment, net. DOE SGIG and other funds reimbursed to the Utility Registrants have been accounted for as CIAC. For Generation, upon retirement, the cost of property is generally charged to accumulated depreciation in accordance with the composite and group methods of depreciation. Upon replacement of an asset, the costs to remove the asset, net of salvage, are capitalized to gross plant when incurred as part of the cost of the newly-installed asset and recorded to depreciation expense over the life of the new asset. Removal costs, net of salvage, incurred for property that will not be replaced is charged to Operating and maintenance expense as incurred. For the Utility Registrants, upon retirement, the cost of property, net of salvage, is charged to accumulated depreciation consistent with the composite and group methods of depreciation. Depreciation expense at ComEd, BGE, Pepco, DPL and ACE includes the estimated cost of dismantling and removing plant from service upon retirement. Actual incurred removal costs are applied against a related regulatory liability or recorded to a regulatory asset if in excess of previously collected removal costs. PECO’s removal costs are capitalized to accumulated depreciation when incurred, and recorded to depreciation expense over the life of the new asset constructed consistent with PECO’s regulatory recovery method. Capitalized Software. Certain costs, such as design, coding, and testing incurred during the application development stage of software projects that are internally developed or purchased for operational use are capitalized within Property, plant and equipment. Such capitalized amounts are amortized ratably over the expected lives of the projects when they become operational, generally not to exceed five years. Certain other capitalized software costs are being amortized over longer lives based on the expected life or pursuant to prescribed regulatory requirements. Capitalized Interest and AFUDC. During construction, Exelon and Generation capitalize the costs of debt funds used to finance non-regulated construction projects. Capitalization of debt funds is recorded as a charge to construction work in progress and as a non-cash credit to interest expense. AFUDC is the cost, during the period of construction, of debt and equity funds used to finance construction projects for regulated operations. AFUDC is recorded to construction work in progress and as a non-cash credit to an allowance that is included in interest expense for debt-related funds and other income and deductions for equity-related funds. The rates used for capitalizing AFUDC are computed under a method prescribed by regulatory authorities. See Note 6 — Property, Plant and Equipment , Note 9 — Jointly Owned Electric Utility Plant and Note 23 — Supplemental Financial Information for additional information regarding property, plant and equipment. Nuclear Fuel (Exelon and Generation) The cost of nuclear fuel is capitalized within Property, plant and equipment and charged to fuel expense using the unit-of-production method. Any potential future SNF disposal fees will be expensed through fuel expense. Additionally, certain on-site SNF storage costs are being reimbursed by the DOE since a DOE (or government-owned) long-term storage facility has not been completed. See Note 22 — Commitments and Contingencies for additional information regarding the cost of SNF storage and disposal. Nuclear Outage Costs (Exelon and Generation) Costs associated with nuclear outages, including planned major maintenance activities, are expensed to Operating and maintenance expense or capitalized to Property, plant and equipment (based on the nature of the activities) in the period incurred. Depreciation and Amortization (All Registrants) Except for the amortization of nuclear fuel, depreciation is generally recorded over the estimated service lives of property, plant and equipment on a straight-line basis using the group, composite or unitary methods of depreciation. The group approach is typically for groups of similar assets that have approximately the same useful lives and the composite approach is used for dissimilar assets that have different lives. Under both methods, a reporting entity depreciates the assets over the average life of the assets in the group. The Utility Registrants' depreciation expense includes the estimated cost of dismantling and removing plant from service upon retirement, which is consistent with each utility's regulatory recovery method. The estimated service lives for the Registrants are based on a combination of depreciation studies, historical retirements, site licenses and management estimates of operating costs and expected future energy market conditions. See Note 8 — Early Plant Retirements for additional information on the impacts of expected and potential early plant retirements. See Note 6 — Property, Plant and Equipment for additional information regarding depreciation. Amortization of regulatory assets and liabilities are recorded over the recovery or refund period specified in the related legislation or regulatory order or agreement. When the recovery or refund period is less than one year, amortization is recorded to the line item in which the deferred cost or income would have originally been recorded in the Utility Registrants’ Consolidated Statements of Operations and Comprehensive Income. Amortization of ComEd’s electric distribution and energy efficiency formula rate regulatory assets and the Utility Registrants' transmission formula rate regulatory assets is recorded to Operating revenues. Amortization of income tax related regulatory assets and liabilities is generally recorded to Income tax expense. With the exception of the regulatory assets and liabilities discussed above, when the recovery period is more than one year, the amortization is generally recorded to Depreciation and amortization in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 4 — Regulatory Matters and Note 23 — Supplemental Financial Information for additional information regarding Generation’s nuclear fuel and ARC, and the amortization of the Utility Registrants' regulatory assets. Asset Retirement Obligations (All Registrants) Generation estimates and recognizes a liability for its legal obligation to perform asset retirement activities even though the timing and/or methods of settlement may be conditional on future events. Generation generally updates its nuclear decommissioning ARO annually, unless circumstances warrant more frequent updates, based on its annual evaluation of cost escalation factors and probabilities assigned to the multiple outcome scenarios within its probability-weighted discounted cash flow models. Generation’s multiple outcome scenarios are generally based on decommissioning cost studies which are updated, on a rotational basis, for each of Generation’s nuclear units at least every five years, unless circumstances warrant more frequent updates. AROs are accreted throughout each year to reflect the time value of money for these present value obligations through a charge to Operating and maintenance expense in the Consolidated Statements of Operations and Comprehensive Income or, in the case of the Utility Registrants' accretion, through an increase to regulatory assets. See Note 15 — Asset Retirement Obligations for additional information. Guarantees (All Registrants) The Registrants recognize, at the inception of a guarantee, a liability for the fair market value of the obligations they have undertaken by issuing the guarantee, including the ongoing obligation to perform over the term of the guarantee in the event that the specified triggering events or conditions occur. The liability that is initially recognized at the inception of the guarantee is reduced as the Registrants are released from risk under the guarantee. Depending on the nature of the guarantee, the release from risk of the Registrant may be recognized only upon the expiration or settlement of the guarantee or by a systematic and rational amortization method over the term of the guarantee. See Note 22 — Commitments and Contingencies for additional information. Asset Impairments Long-Lived Assets (All Registrants). The Registrants e |
Variable Interest Entities (All
Variable Interest Entities (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Variable Interest Entity [Abstract] | |
Variable Interest Entity Disclosure [Text Block] | Variable Interest Entities (All Registrants) A VIE is a legal entity that possesses any of the following characteristics: an insufficient amount of equity at risk to finance its activities, equity owners who do not have the power to direct the significant activities of the entity (or have voting rights that are disproportionate to their ownership interest), or equity owners who do not have the obligation to absorb expected losses or the right to receive the expected residual returns of the entity. Companies are required to consolidate a VIE if they are its primary beneficiary, which is the enterprise that has the power to direct the activities that most significantly affect the entity’s economic performance. At December 31, 2018 and 2017 , Exelon, Generation, PHI and ACE collectively consolidated five VIEs or VIE groups for which the applicable Registrant was the primary beneficiary (see Consolidated Variable Interest Entities below). As of December 31, 2018 and 2017 , Exelon and Generation collectively had significant interests in seven other VIEs for which the applicable Registrant does not have the power to direct the entities’ activities and, accordingly, was not the primary beneficiary (see Unconsolidated Variable Interest Entities below). Consolidated Variable Interest Entities The carrying amounts and classification of the consolidated VIEs’ assets and liabilities included in the Registrants' consolidated financial statements at December 31, 2018 and 2017 are as follows: December 31, 2018 Exelon (a) Generation PHI (a) ACE Current assets $ 938 $ 931 $ 7 4 Noncurrent assets 9,071 9,045 26 19 Total assets $ 10,009 $ 9,976 $ 33 $ 23 Current liabilities $ 274 $ 252 $ 22 19 Noncurrent liabilities 3,280 3,233 47 40 Total liabilities $ 3,554 $ 3,485 $ 69 $ 59 December 31, 2017 Exelon (a) Generation PHI (a) ACE Current assets $ 662 $ 652 $ 10 $ 6 Noncurrent assets 9,317 9,286 31 23 Total assets $ 9,979 $ 9,938 $ 41 $ 29 Current liabilities $ 308 $ 272 $ 36 $ 32 Noncurrent liabilities 3,316 3,250 66 58 Total liabilities $ 3,624 $ 3,522 $ 102 $ 90 __________ (a) Includes certain purchase accounting adjustments not pushed down to the ACE standalone entity. Except as specifically noted below, the assets in the table above are restricted for settlement of the VIE obligations and the liabilities in the table can only be settled using VIE resources. As of December 31, 2018 and 2017 , Exelon's and Generation's consolidated VIEs consist of: Investments in Other Energy Related Companies During 2015, Generation sold 69% of its equity interest in a company to a tax equity investor. The company holds an equity method investment in a distributed energy company that is an unconsolidated VIE (see unconsolidated VIE section for additional details). Generation and the tax equity investor contributed a total of $227 million of equity in proportion to their ownership interests to the company. The company meets the definition of a VIE because it has a similar structure to a limited partnership and the limited partners do not have kick-out rights with respect to the general partner. Generation is the primary beneficiary because Generation manages the day-to-day activities of the entity. During the fourth quarter of 2017 Generation acquired a controlling financial interest in an energy development company. The company is in the development stage and requires additional subordinated financial support from the equity holders to fund activities. Generation is the majority owner with a 62% equity interest and has the power to direct the activities that most significantly affect the economic performance of the company. Renewable Energy Project Companies In July 2017, Generation sold a 49% interest in EGRP to an outside investor for $400 million of cash plus immaterial working capital and other customary post-closing adjustments. EGRP meets the definition of a VIE because the EGRP has a similar structure to a limited partnership and the limited partners do not have kick out rights with respect to the general partner. Generation is the primary beneficiary because Generation manages the day-to-day activities of the entity; therefore, Generation will continue to consolidate EGRP. EGRP is a collection of wind and solar project entities and some of these project entities are VIEs that are consolidated by EGRP. The details relating to these VIEs are discussed below. Generation owns a number of limited liability companies that build, own, and operate solar and wind power facilities some of which are owned by EGRP. While Generation or EGRP owns 100% of the solar entities and 100% of the majority of the wind entities, it has been determined that certain of the solar and wind entities are VIEs because the entities require additional subordinated financial support in the form of a parental guarantee of debt, loans from the customers in order to obtain the necessary funds for construction of the solar facilities, or the customers absorb price variability from the entities through the fixed price power and/or REC purchase agreements. Generation is the primary beneficiary of these solar and wind entities that qualify as VIEs because Generation controls the design, construction, and operation of the facilities. Generation provides operating and capital funding to the solar and wind entities for ongoing construction, operations and maintenance and there is limited recourse related to Generation related to certain solar and wind entities. While Generation or EGRP owns 100% of the majority of the wind entities, four of the projects have noncontrolling equity interests of 1% held by third parties and one of the projects has noncontrolling equity interests related to its Class B Membership Interest (see additional details below). The entities with noncontrolling equity interests of 1% held by third parties meet the definition of a VIE because the entities have noncontrolling equity interest holders that absorb variability from the wind projects. Generation’s or the EGRP's current economic interests in three of these projects is significantly greater than its stated contractual governance rights and all of these projects have reversionary interest provisions that provide the noncontrolling interest holder with a purchase option, certain of which are considered bargain purchase prices, which, if exercised, transfers ownership of the projects to the noncontrolling interest holder upon either the passage of time or the achievement of targeted financial returns. The ownership agreements with the noncontrolling interests state that Generation or EGRP are to provide financial support to the projects in proportion to its current 99% economic interests in the projects. Generation provides operating and capital funding to the wind project entities for ongoing construction, operations and maintenance and there is limited recourse to Generation related to certain wind project entities. However, no additional support to these projects beyond what was contractually required has been provided. Generation is the primary beneficiary of these wind entities because Generation controls the design, construction, and operation of the facilities. In December 2016, Generation sold 100% of the Class B Membership Interests to a tax equity investor and retained 100% of the Class A Membership Interests of its equity interest in one of its wind entities that was previously consolidated under the voting interest model and was subsequently contributed to EGRP in 2017. The wind entity meets the definition of a VIE because the company has a similar structure to a limited partnership and the limited partners do not have kick-out rights with respect to the general partner. While Generation is the minority interest holder, Generation is the primary beneficiary, because Generation manages the day-to-day activities of the entity. Therefore, the entity continues to be consolidated by Generation. In 2017, Generation’s interests in EGRP were contributed to and are pledged for the ExGen Renewables IV non-recourse debt project financing structure. Refer to Note 13 — Debt and Credit Agreements for additional information on ExGen Renewables IV and ITEM 2. PROPERTIES for additional details on the specific projects included within EGRP. Retail Power and Gas Companies In March 2014, Generation began consolidating retail power and gas VIEs for which Generation is the primary beneficiary as a result of energy supply contracts that give Generation the power to direct the activities that most significantly affect the economic performance of the entities. Generation does not have an equity ownership interest in these entities, but provides approximately $34 million in credit support for the retail power and gas companies for which Generation is the sole supplier of energy. These entities are included in Generation’s consolidated financial statements, and the consolidation of the VIEs do not have a material impact on Generation’s financial results or financial condition. CENG CENG is a joint venture between Generation and EDF. On April 1, 2014, Generation, CENG, and subsidiaries of CENG executed the Nuclear Operating Services Agreement (NOSA) pursuant to which Generation now conducts all activities associated with the operations of the CENG fleet and provides corporate and administrative services to CENG and the CENG fleet for the remaining life of the CENG nuclear plants as if they were a part of the Generation nuclear fleet, subject to the CENG member rights of EDF. As a result of executing the NOSA, CENG qualifies as a VIE due to the disproportionate relationship between Generation’s 50.01% equity ownership interest and its role in conducting the operational activities of CENG and the CENG fleet conveyed through the NOSA. Further, since Generation is conducting the operational activities of CENG and the CENG fleet, Generation qualifies as the primary beneficiary of CENG and, therefore, is required to consolidate the results of operations and financial position of CENG. Exelon and Generation, where indicated, provide the following support to CENG: • under power purchase agreements with CENG, Generation purchased or will purchase 50.01% of the available output generated by the CENG nuclear plants not subject to other contractual agreements from January 2015 through the end of the operating life of each respective plant. However, pursuant to amendments dated March 31, 2015, the energy obligations under the Ginna Nuclear Power Plant (Ginna) PPAs were suspended during the term of the RSSA, through the end of March 31, 2017. With the expiration of the RSSA, the PPA was reinstated beginning April 1, 2017. (see Note 4 — Regulatory Matters for additional details), • Generation provided a $400 million loan to CENG. As of December 31, 2018 , the remaining obligation is $196 million , including accrued interest. The remaining balance was fully paid by CENG in January 2019. • Generation executed an Indemnity Agreement pursuant to which Generation agreed to indemnify EDF against third-party claims that may arise from any future nuclear incident (as defined in the Price-Anderson Act) in connection with the CENG nuclear plants or their operations. Exelon guarantees Generation’s obligations under this Indemnity Agreement. (See Note 22 — Commitments and Contingencies for more details), • Generation and EDF share in the $688 million of contingent payment obligations for the payment of contingent retrospective premium adjustments for the nuclear liability insurance, and • Exelon has executed an agreement to provide up to $245 million to support the operations of CENG as well as a $165 million guarantee of CENG’s cash pooling agreement with its subsidiaries. As of December 31, 2018 and 2017 , Exelon's, PHI's and ACE's consolidated VIE consists of: ACE Transition Funding A special purpose entity formed by ACE for the purpose of securitizing authorized portions of ACE’s recoverable stranded costs through the issuance and sale of transition bonds. Proceeds from the sale of each series of transition bonds by ATF were transferred to ACE in exchange for the transfer by ACE to ATF of the right to collect a non-bypassable Transition Bond Charge from ACE customers pursuant to bondable stranded costs rate orders issued by the NJBPU in an amount sufficient to fund the principal and interest payments on transition bonds and related taxes, expenses and fees. During the three years ended December 31, 2018 , 2017 and 2016 , ACE transferred $30 million , $48 million and $60 million to ATF, respectively. As of December 31, 2018 and 2017 , ComEd, PECO, BGE, Pepco and DPL do not have any material consolidated VIEs. Assets and Liabilities of Consolidated VIEs Included within the balances above are assets and liabilities of certain consolidated VIEs for which the assets can only be used to settle obligations of those VIEs, and liabilities that creditors, or beneficiaries, do not have recourse to the general credit of the Registrants. As of December 31, 2018 and 2017 , these assets and liabilities primarily consisted of the following: December 31, 2018 Exelon (a) Generation PHI (a) ACE Cash and cash equivalents $ 414 $ 414 $ — $ — Restricted cash and cash equivalents 66 62 4 4 Accounts receivable, net Customer 146 146 — — Other 23 23 — — Inventory Materials and supplies 212 212 — — Other current assets 52 49 3 — Total current assets 913 906 7 4 Property, plant and equipment, net 6,145 6,145 — — Nuclear decommissioning trust funds 2,351 2,351 — — Other noncurrent assets 258 232 26 19 Total noncurrent assets 8,754 8,728 26 19 Total assets $ 9,667 $ 9,634 $ 33 $ 23 Long-term debt due within one year $ 87 $ 66 $ 21 $ 18 Accounts payable 96 96 — — Accrued expenses 72 72 1 1 Unamortized energy contract liabilities 15 15 — — Other current liabilities 3 3 — — Total current liabilities 273 252 22 19 Long-term debt 1,072 1,025 47 40 Asset retirement obligations 2,160 2,160 — — Unamortized energy contract liabilities 1 1 — — Other noncurrent liabilities 42 42 — — Total noncurrent liabilities 3,275 3,228 47 40 Total liabilities $ 3,548 $ 3,480 $ 69 $ 59 __________ (a) Includes certain purchase accounting adjustments not pushed down to the ACE standalone entity. December 31, 2017 Exelon (a) Generation PHI (a) ACE Cash and cash equivalents $ 126 $ 126 $ — $ — Restricted cash and cash equivalents 64 58 6 6 Accounts receivable, net Customer 170 170 — — Other 25 25 — — Inventory Materials and supplies 205 205 — — Other current assets 45 41 4 — Total current assets 635 625 10 6 Property, plant and equipment, net 6,186 6,186 — — Nuclear decommissioning trust funds 2,502 2,502 — — Other noncurrent assets 274 243 31 23 Total noncurrent assets 8,962 8,931 31 23 Total assets $ 9,597 $ 9,556 $ 41 $ 29 Long-term debt due within one year $ 102 $ 67 $ 35 $ 31 Accounts payable 114 114 — — Accrued expenses 67 66 1 1 Unamortized energy contract liabilities 18 18 — — Other current liabilities 7 7 — — Total current liabilities 308 272 36 32 Long-term debt 1,154 1,088 66 58 Asset retirement obligations 2,035 2,035 — — Other noncurrent liabilities 121 121 — — Total noncurrent liabilities 3,310 3,244 66 58 Total liabilities $ 3,618 $ 3,516 $ 102 $ 90 __________ (a) Includes certain purchase accounting adjustments not pushed down to the ACE standalone entity. Unconsolidated Variable Interest Entities Exelon’s and Generation’s variable interests in unconsolidated VIEs generally include equity investments and energy purchase and sale contracts. For the equity investments, the carrying amount of the investments is reflected in Exelon’s and Generation’s Consolidated Balance Sheets in Investments. For the energy purchase and sale contracts (commercial agreements), the carrying amount of assets and liabilities in Exelon’s and Generation’s Consolidated Balance Sheets that relate to their involvement with the VIEs are predominately related to working capital accounts and generally represent the amounts owed by, or owed to, Exelon and Generation for the deliveries associated with the current billing cycles under the commercial agreements. Further, Exelon and Generation have not provided material debt or equity support, liquidity arrangements or performance guarantees associated with these commercial agreements. As of December 31, 2018 and 2017 , Exelon and Generation had significant unconsolidated variable interests in seven VIEs for which Exelon or Generation, as applicable, was not the primary beneficiary. These interests include certain equity method investments and certain commercial agreements. Exelon and Generation only include unconsolidated VIEs that are individually material in the tables below. However, Exelon and Generation have several individually immaterial VIEs that in aggregate represent a total investment of $15 million and $13 million , respectively, as of December 31, 2018 . These immaterial VIEs are equity and debt securities in energy development companies. As of December 31, 2018 , the maximum exposure to loss related to these securities included in Investments in Exelon's and Generation's Consolidated Balance Sheets is limited to the $15 million and $13 million , respectively. The following tables present summary information about Exelon and Generation’s significant unconsolidated VIE entities: December 31, 2018 Commercial Agreement VIEs Equity Investment VIEs Total Total assets (a) $ 597 $ 472 $ 1,069 Total liabilities (a) 37 222 259 Exelon's ownership interest in VIE (a) — 223 223 Other ownership interests in VIE (a) 560 27 587 Registrants’ maximum exposure to loss: Carrying amount of equity method investments — 223 223 Contract intangible asset 7 — 7 Net assets pledged for Zion Station decommissioning (b) — — — December 31, 2017 Commercial Agreement VIEs Equity Investment VIEs Total Total assets (a) $ 625 $ 509 $ 1,134 Total liabilities (a) 37 228 265 Exelon's ownership interest in VIE (a) — 251 251 Other ownership interests in VIE (a) 588 30 618 Registrants’ maximum exposure to loss: Carrying amount of equity method investments — 251 251 Contract intangible asset 8 — 8 Net assets pledged for Zion Station decommissioning (b) 2 — 2 __________ (a) These items represent amounts on the unconsolidated VIE balance sheets, not in Exelon’s or Generation’s Consolidated Balance Sheets. These items are included to provide information regarding the relative size of the unconsolidated VIEs. (b) These items represent amounts in Exelon’s and Generation’s Consolidated Balance Sheets related to the asset sale agreement with ZionSolutions, LLC. The net assets pledged for Zion Station decommissioning includes gross pledged assets of $9 million and $39 million as of December 31, 2018 and December 31, 2017 , respectively; offset by payables to ZionSolutions LLC of $9 million and $37 million as of December 31, 2018 and December 31, 2017 , respectively. These items are included to provide information regarding the relative size of the ZionSolutions, LLC unconsolidated VIE. For each of the unconsolidated VIEs, Exelon and Generation have assessed the risk of a loss equal to their maximum exposure to be remote and, accordingly, Exelon and Generation have not recognized a liability associated with any portion of the maximum exposure to loss. In addition, there are no material agreements with, or commitments by, third parties that would materially affect the fair value or risk of their variable interests in these VIEs. As of December 31, 2018 and 2017 , Exelon's and Generation's unconsolidated VIEs consist of: Energy Purchase and Sale Agreements Generation has several energy purchase and sale agreements with generating facilities. Generation has evaluated the significant agreements, ownership structures and risks of each entity, and determined that certain of the entities are VIEs because the entity absorbs risk through the sale of fixed price power and renewable energy credits. Generation has reviewed the entities and has determined that Generation is not the primary beneficiary of the VIEs because Generation does not have the power to direct the activities that most significantly impact the VIEs economic performance. ZionSolutions Generation has an asset sale agreement with EnergySolutions, Inc. and certain of its subsidiaries, including ZionSolutions, LLC (ZionSolutions), which is further discussed in Note 15 — Asset Retirement Obligations . Under this agreement, ZionSolutions can put the assets and liabilities back to Generation when decommissioning activities under the asset sale agreement are complete. Generation has evaluated this agreement and determined that, through the put option, it has a variable interest in ZionSolutions but is not the primary beneficiary. As a result, Generation has concluded that consolidation is not required. Other than the asset sale agreement, Exelon and Generation do not have any contractual or other obligations to provide additional financial support and ZionSolutions’ creditors do not have any recourse to Exelon’s or Generation’s general credit. Investment in Distributed Energy Companies In July 2014, Generation entered into an arrangement to purchase a 90% equity interest and 90% of the tax attributes of a distributed energy company. Generation contributed a total $85 million of equity. The distributed energy company meets the definition of a VIE because the company has a similar structure to a limited partnership and the limited partners do not have kick-out rights of the general partner. Generation is not the primary beneficiary; therefore, the investment continues to be recorded using the equity method. During 2015, a company that is consolidated by Generation as a VIE entered into an arrangement to purchase a 90% equity interest and 99% of the tax attributes of another distributed energy company (see additional details in the Consolidated Variable Interest Entities section above). The equity holders (of which Generation is one) contributed to the distributed energy company a total of $227 million of equity in proportion to their ownership interests. The equity holders provided a parental guarantee of up to $275 million in support of equity contributions to the distributed energy company. As all equity contributions were made as of the first quarter of 2017, there is no further payment obligation under the parental guarantee. The distributed energy company meets the definition of a VIE because the company has a similar structure to a limited partnership and the limited partners do not have kick-out rights of the general partner. Generation is not the primary beneficiary; therefore, the investment is recorded using the equity method. Both distributed energy companies from the 2015 and 2014 arrangements are considered related parties to Generation. ComEd and PECO The financing trust of ComEd, ComEd Financing III, and the financing trusts of PECO, PECO Trust III and PECO Trust IV, are not consolidated in Exelon’s, ComEd’s, or PECO’s financial statements. These financing trusts were created to issue mandatorily redeemable trust preferred securities. ComEd and PECO have concluded that they do not have a significant variable interest in ComEd Financing III, PECO Trust III, or PECO Trust IV as each Registrant financed its equity interest in the financing trusts through the issuance of subordinated debt and, therefore, has no equity at risk. See Note 13 — Debt and Credit Agreements for additional information. |
Revenue Recognition Revenue Rec
Revenue Recognition Revenue Recognition (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Revenue from Contract with Customer (All Registrants) [Abstract] | |
Revenue from Contract with Customer [Text Block] | 3. Revenue from Contracts with Customers (All Registrants) The Registrants recognize revenue from contracts with customers to depict the transfer of goods or services to customers at an amount that the entities expect to be entitled to in exchange for those goods or services. Generation’s primary sources of revenue include competitive sales of power, natural gas, and other energy-related products and services. The Utility Registrants’ primary sources of revenue include regulated electric and gas tariff sales, distribution and transmission services. The performance obligations associated with these sources of revenue are further discussed below. Unless otherwise noted, for each of the significant revenue categories and related performance obligations described below, the Registrants have the right to consideration from the customer in an amount that corresponds directly with the value transferred to the customer for the performance completed to date. Therefore, the Registrant's have elected to use the right to invoice practical expedient for the contracts within these revenue categories and generally recognize revenue in the amount for which they have the right to invoice the customer. As a result, there are generally no significant judgments used in determining or allocating the transaction price. Competitive Power Sales (Exelon and Generation) Generation sells power and other energy-related commodities to both wholesale and retail customers across multiple geographic regions through its customer-facing business, Constellation. Power sale contracts generally contain various performance obligations including the delivery of power and other energy-related commodities such as capacity, ZECs, RECs or other ancillary services. Certain performance obligations such as power and capacity are generally delivered over time whereas other performance obligations such as RECs and ZECs are generally delivered at a point in time. In either case, revenues related to all of the performance obligations in such bundled power sale contracts are generally recognized concurrently as the power is generated. Except as noted in the paragraph below, there are no significant judgments in allocating the transaction price since all performance obligations are satisfied simultaneously upon the generation of power. Payment terms generally require that the customers pay for the power or the energy-related commodity within the month following delivery to the customer and there are generally no significant financing components. Certain contracts may contain limits on the total amount of revenue we are able to collect over the entire term of the contract. In such cases, the Registrants estimate the total consideration expected to be received over the term of the contract net of the constraint and allocate the expected consideration to the performance obligations in the contract such that revenue is recognized ratably over the term of the entire contract as the performance obligations are satisfied. Competitive Natural Gas Sales (Exelon and Generation) Generation sells natural gas on a full requirements basis or for an agreed upon volume to both commercial and residential customers. The primary performance obligation associated with natural gas sale contracts is the delivery of the natural gas to the customer. Revenues related to the sale of natural gas are recognized over time as the natural gas is delivered to and consumed by the customer. Payment from customers is typically due within the month following delivery of the natural gas to the customer and there are generally no significant financing components. Other Competitive Products and Services (Exelon and Generation) Generation also sells other energy-related products and services such as long-term construction and installation of energy efficiency assets and new power generating facilities, primarily to commercial and industrial customers. These contracts generally contain a single performance obligation, which is the construction and/or installation of the asset for the customer. The average contract term for these projects is approximately 18 months. Revenues, and associated costs, are recognized throughout the contract term using an input method to measure progress towards completion. The method recognizes revenue based on the various inputs used to satisfy the performance obligation, such as costs incurred and total labor hours expended. The total amount of revenue that will be recognized is based on the agreed upon contractually-stated amount. Payments from customers are typically due within 30 or 45 days from the date the invoice is generated and sent to the customer. Regulated Electric and Gas Tariff Sales (Exelon and the Utility Registrants) The Utility Registrants sell electricity and electricity distribution services to residential, commercial, industrial and governmental customers through regulated tariff rates approved by their state regulatory commissions. PECO, BGE and DPL also sell natural gas and gas distribution services to residential, commercial, and industrial customers through regulated tariff rates approved by their state regulatory commissions. The performance obligation associated with these tariff sale contracts is the delivery of electricity and/or natural gas. Tariff sales are generally considered daily contracts given that customers can discontinue service at any time. Revenues are generally recognized over time (each day) as the electricity and/or natural gas is delivered to customers. Payment terms generally require that customers pay for the services within the month following delivery of the electricity or natural gas to the customer and there are generally no significant financing components or variable consideration. Electric and natural gas utility customers have the choice to purchase electricity or natural gas from competitive electric generation and natural gas suppliers. While the Utility Registrants are required under state legislation to bill their customers for the supply and distribution of electricity and/or natural gas, they recognize revenue related only to the distribution services when customers purchase their electricity or natural gas from competitive suppliers. Regulated Transmission Services (Exelon and the Utility Registrants) Under FERC’s open access transmission policy, the Utility Registrants, as owners of transmission facilities, are required to provide open access to their transmission facilities under filed tariffs at cost-based rates approved by FERC. The Utility Registrants are members of PJM, the regional transmission organization designated by FERC to coordinate the movement of wholesale electricity in PJM’s region, which includes portions of the mid-Atlantic and Midwest. In accordance with FERC-approved rules, the Utility Registrants and other transmission owners in the PJM region make their transmission facilities available to PJM, which directs and controls the operation of these transmission facilities and accordingly compensates the Utility Registrants and other transmission owners. The performance obligations associated with the Utility Registrants’ contract with PJM include (i) Network Integration Transmission Services (NITS), (ii) scheduling, system control and dispatch services, and (iii) access to the wholesale grid. These performance obligations are satisfied over time, and Utility Registrants utilize output methods to measure the progress towards their completion. Passage of time is used for NITS and access to the wholesale grid and MWhs of energy transported over the wholesale grid is used for scheduling, system control and dispatch services. PJM pays the Utility Registrants for these services on a weekly basis and there are no financing components or variable consideration. Costs to Obtain or Fulfill a Contract with a Customer (Exelon and Generation) Generation incurs incremental costs in order to execute certain retail power and gas sales contracts. These costs primarily relate to retail broker fees and sales commissions. Generation has capitalized such contract acquisition costs in the amount of $32 million and $26 million as of December 31, 2018 and December 31, 2017 , respectively, within Other current assets and Other deferred debits in Exelon’s and Generation’s Consolidated Balance Sheets. These costs are capitalized when incurred and amortized using the straight-line method over the average length of such retail contracts, which is approximately 2 years. Exelon and Generation recognized amortization expense associated with these costs in the amount of $22 million and $30 million for the twelve months ended December 31, 2018 , and December 31, 2017 , respectively, within Operating and maintenance expense in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. Generation does not incur material costs to fulfill contracts with customers that are not already capitalized under existing guidance. In addition, the Utility Registrants do not incur any material costs to obtain or fulfill contracts with customers. Contract Balances (All Registrants) Contract Assets Generation records contract assets for the revenue recognized on the construction and installation of energy efficiency assets and new power generating facilities before Generation has an unconditional right to bill for and receive the consideration from the customer. These contract assets are subsequently reclassified to receivables when the right to payment becomes unconditional. Generation records contract assets and contract receivables within Other current assets and Accounts receivable, net - Customer, respectively, within Exelon’s and Generation’s Consolidated Balance Sheets. The following table provides a rollforward of the contract assets reflected in Exelon's and Generation's Consolidated Balance Sheets from January 1, 2018 to December 31, 2018 : Contract Assets Exelon and Generation Balance as of January 1, 2018 $ 283 Increases as a result of changes in the estimate of the stage of completion 50 Amounts reclassified to receivables (146 ) Balance at December 31, 2018 $ 187 The Utility Registrants do not have any contract assets. Contract Liabilities Generation records contract liabilities when consideration is received or due prior to the satisfaction of the performance obligations. These contract liabilities primarily relate to upfront consideration received or due for equipment service plans, solar panel leases and the Illinois ZEC program that introduces a cap on the total consideration to be received by Generation. The Generation contract liability related to the Illinois ZEC program includes certain amounts with ComEd that are eliminated in consolidation in Exelon’s Consolidated Statements of Operations and Consolidated Balance Sheets. Generation records contract liabilities within Other current liabilities and Other noncurrent liabilities within Exelon’s and Generation’s Consolidated Balance Sheets. The following table provides a rollforward of the contract liabilities reflected in Exelon's and Generation's Consolidated Balance Sheet from January 1, 2018 to December 31, 2018 : Contract Liabilities Exelon Generation Balance as of January 1, 2018 $ 35 $ 35 Increases as a result of additional cash received or due 179 465 Amounts recognized into revenues (187 ) (458 ) Balance at December 31, 2018 $ 27 $ 42 The Utility Registrants also record contract liabilities when consideration is received prior to the satisfaction of the performance obligations. As of December 31, 2018 and December 31, 2017 , the Utility Registrants' contract liabilities were immaterial. Transaction Price Allocated to Remaining Performance Obligations (All Registrants) The following table shows the amounts of future revenues expected to be recorded in each year for performance obligations that are unsatisfied or partially unsatisfied as of December 31, 2018 . Generation has elected the exemption which permits the exclusion from this disclosure of certain variable contract consideration. As such, the majority of Generation’s power and gas sales contracts are excluded from this disclosure as they contain variable volumes and/or variable pricing. Thus, this disclosure only includes contracts for which the total consideration is fixed and determinable at contract inception. The average contract term varies by customer type and commodity but ranges from one month to several years. The majority of the Utility Registrants’ tariff sale contracts are generally day-to-day contracts and, therefore, do not contain any future, unsatisfied performance obligations to be included in this disclosure. Further, the Utility Registrants have elected the exemption to not disclose the transaction price allocation to remaining performance obligations for contracts with an original expected duration of one year or less. As such, gas and electric tariff sales contracts and transmission revenue contracts are excluded from this disclosure. 2019 2020 2021 2022 2023 and thereafter Total Exelon $ 631 $ 329 $ 119 $ 47 $ 138 $ 1,264 Generation 631 329 119 47 138 1,264 Revenue Disaggregation (All Registrants) The Registrants disaggregate revenue recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. See Note 24 — Segment Information for the presentation of the Registrant's revenue disaggregation. |
Regulatory Matters (All Registr
Regulatory Matters (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Regulated Operations [Abstract] | |
Regulatory Matters (All Registrants) | Regulatory Matters (All Registrants) The following matters below discuss the status of material regulatory and legislative proceedings of the Registrants. Utility Regulatory Matters (Exelon and the Utility Registrants) Distribution Base Rate Case Proceedings The following tables show the completed and pending distribution base rate case proceedings in 2018. Completed Distribution Base Rate Case Proceedings Registrant/Jurisdiction Filing Date Requested Revenue Requirement Increase (Decrease) Approved Revenue Requirement Increase (Decrease) Approved ROE Approval Date Rate Effective Date ComEd - Illinois (Electric) (b) April 16, 2018 $ (23 ) (a) $ (24 ) (a) 8.69 % December 4, 2018 January 1, 2019 PECO - Pennsylvania (Electric) (c) March 29, 2018 $ 82 (a) $ 25 (a) N/A December 20, 2018 January 1, 2019 BGE - Maryland (Natural Gas) June 8, 2018 (amended August 24, 2018 and October 12, 2018) $ 61 $ 43 9.8 % January 4, 2019 January 4, 2019 Pepco - Maryland (Electric) January 2, 2018 (amended February 5, 2018) $ 3 (a) $ (15 ) (a) 9.5 % May 31, 2018 June 1, 2018 Pepco - District of Columbia (Electric) (d) December 19, 2017 (amended February 9, 2018) $ 66 $ (24 ) (a) 9.525 % August 9, 2018 August 13, 2018 DPL - Maryland (Electric) (e) July 14, 2017 (amended November 16, 2017) $ 19 $ 13 9.5 % February 9, 2018 February 9, 2018 DPL - Delaware (Electric) August 17, 2017 (amended February 9, 2018) $ 12 (a) $ (7 ) (a) 9.7 % August 21, 2018 March 17, 2018 DPL - Delaware (Natural Gas) August 17, 2017 (amended February 9, 2018) $ 4 (a) $ (4 ) (a) 9.7 % November 8, 2018 March 17, 2018 __________ (a) Includes the annual ongoing TCJA tax savings further discussed below. (b) Pursuant to EIMA and FEJA, ComEd’s electric distribution rates are established through a performance-based formula, which sunsets at the end of 2022. ComEd is required to file an annual update to its electric distribution formula rate on or before May 1 st , with resulting rates effective in January of the following year. ComEd’s annual electric distribution formula rate update is based on prior year actual costs and current year projected capital additions (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect for the prior year and actual costs incurred from the year (annual reconciliation). ComEd’s 2018 approved revenue requirement above reflects a decrease of $58 million for the initial year revenue requirement for 2018 and an increase of $34 million related to the annual reconciliation for 2017. The revenue requirement for 2018 and the annual reconciliation for 2017 provides for a weighted average debt and equity return on distribution rate base of 6.52% inclusive of an allowed ROE of 8.69% , reflecting the average rate on 30-year treasury notes plus 580 basis points. See table below for ComEd's regulatory assets associated with its electric distribution formula rate. During the first quarter of 2018, ComEd revised its electric distribution formula rate to implement revenue decoupling provisions provided for under FEJA. As a result of this revision, ComEd’s electric distribution formula rate revenues are not impacted by abnormal weather, usage per customer or numbers of customers. ComEd began reflecting the impacts of this change in its Operating revenues and electric distribution formula rate regulatory asset in the first quarter of 2017. (c) The PECO base rate case proceeding was resolved through a settlement agreement, which did not specify an approved ROE. (d) On September 7, 2018, Pepco submitted an updated filing for an increase of $4 million to the customer base rate credit established in connection with the merger between Exelon and PHI for residential customers, representing the TCJA benefits for the period January 1, 2018 through August 12, 2018. (e) The DPL Maryland base rate case proceeding was resolved through a settlement agreement, which did not specify an overall ROE. The settlement agreement included an ROE of 9.5% solely for purposes of calculating AFUDC and regulatory asset carrying costs. In the second quarter of 2018, DPL discovered a rate design issue in Maryland such that the current rates were not sufficient to collect the full amount of the $13 million revenue increase agreed to by the parties in the recent settlement. On September 5, 2018, the MDPSC approved DPL’s proposed revisions to resolve the rate design issue on a prospective basis, effective September 5, 2018. Pending Distribution Base Rate Case Proceedings Registrant/Jurisdiction Filing Date Requested Revenue Requirement Increase Requested ROE Expected Approval Timing ACE - New Jersey (Electric) August 21, 2018 (amended November 19, 2018) $ 122 (a) 10.1 % Third quarter of 2019 (b) Pepco - Maryland (Electric) January 15, 2019 $ 30 10.3 % Third quarter of 2019 __________ (a) Requested increase is before New Jersey sales and use tax and includes $40 million of higher depreciation expense related to its updated depreciation study and the annual ongoing TCJA tax savings further discussed below. (b) ACE plans to put interim rates in effect on or around May 21, 2019, subject to refund, as allowed by the regulation. Transmission Formula Rates Transmission Formula Rate (Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE). ComEd’s, BGE’s, Pepco's, DPL's and ACE's transmission rates are each established based on a FERC-approved formula. ComEd, BGE, Pepco, DPL and ACE are required to file an annual update to the FERC-approved formula on or before May 15, with the resulting rates effective on June 1 of the same year. The annual formula rate update is based on prior year actual costs and current year projected capital additions (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect beginning June 1 of the prior year and actual costs incurred for that year (annual reconciliation). For 2018, the following total increases/(decreases) were included in ComEd’s, BGE’s, Pepco's, DPL's and ACE's electric transmission formula rate filings: Registrant Initial Revenue Requirement (Decrease) Increase (b) Annual Reconciliation Increase/(Decrease) Total Revenue Requirement (Decrease) Increase Allowed Return on Rate Base (d) Allowed ROE (e) ComEd (a) $ (44 ) $ 18 $ (26 ) 8.32 % 11.50 % BGE (a) 10 4 26 (c) 7.61 % 10.50 % Pepco 6 2 8 7.82 % 10.50 % DPL 14 13 27 7.29 % 10.50 % ACE (a) 4 (4 ) — 8.02 % 10.50 % __________ (a) The time period for any formal challenges to the annual transmission formula rate update filings expired with no formal challenges submitted. (b) The initial revenue requirement changes reflect the annual benefit of lower income tax rates effective January 1, 2018 resulting from the enactment of the TCJA of $69 million , $18 million , $13 million , $12 million and $11 million for ComEd, BGE, Pepco, DPL and ACE, respectively. They do not reflect the pass back or recovery of income tax-related regulatory liabilities or assets, including those established upon enactment of the TCJA. See further discussion below. (c) The change in BGE's transmission revenue requirement includes a FERC approved dedicated facilities charge of $12 million to recover the costs of providing transmission service to specifically designated load by BGE. (d) Represents the weighted average debt and equity return on transmission rate bases. (e) As part of the FERC-approved settlement of ComEd’s 2007 transmission rate case, the rate of return on common equity is 11.50% , inclusive of a 50-basis-point incentive adder for being a member of a RTO, and the common equity component of the ratio used to calculate the weighted average debt and equity return for the transmission formula rate is currently capped at 55% . As part of the FERC-approved settlement of the ROE complaint against BGE, Pepco, DPL and ACE, the rate of return on common equity is 10.50% , inclusive of a 50-basis-point incentive adder for being a member of a RTO. Pending Transmission Formula Rate (Exelon and PECO). On May 1, 2017, PECO filed a request with FERC seeking approval to update its transmission rates and change the manner in which PECO’s transmission rate is determined from a fixed rate to a formula rate. The formula rate will be updated annually to ensure that under this rate customers pay the actual costs of providing transmission services. The formula rate filing includes a requested increase of $22 million to PECO’s annual transmission revenues and a requested rate of return on common equity of 11% , inclusive of a 50 basis point adder for being a member of a regional transmission organization. PECO requested that the new transmission rate be effective as of July 2017. On June 27, 2017, FERC issued an Order accepting the filing and suspending the proposed rates until December 1, 2017, subject to refund, and set the matter for hearing and settlement judge procedures. On May 4, 2018, the Chief Administrative Law Judge terminated settlement judge procedures and designated a new presiding judge. PECO cannot predict the outcome of this proceeding, or the transmission formula FERC may approve. On May 11, 2018, pursuant to the transmission formula rate request discussed above, PECO made its first annual formula rate update, which included a revenue decrease of $6 million. The revenue decrease of $6 million included an approximately $20 million reduction as a result of the tax savings associated with the TCJA. The updated transmission rate was effective June 1, 2018, subject to refund. Tax Cuts and Jobs Act The Utility Registrants have made filings with their state regulatory commissions to pass back tax savings related to TCJA to their distribution customers, which are detailed below. The tax savings include the benefit of lower federal income tax rates and the settlement of a portion of the deferred income tax regulatory liabilities established upon the enactment of the TCJA. The ongoing annual TCJA tax savings in the table below represent the annual savings for distribution customers reflected in the initial customers rates approved after the TCJA. Subsequent annual TCJA tax savings will be approved as part of the annual update to the electric distribution formula rate for ComEd or base rate case proceedings for PECO, BGE, Pepco, DPL and ACE. Ongoing TCJA Tax Savings Stub Period Bill Credit from TCJA Tax Savings Registrant/Jurisdiction Amount Approval Date Rate Effective Date Stub Period Approval Date Refund Amount/Period ComEd - Illinois (Electric) $ 201 January 18, 2018 February 1, 2018 Not applicable PECO - Pennsylvania (Electric) $ 71 December 20, 2018 January 1, 2019 January 1, 2018 - December 31, 2018 December 20, 2018 $67 / 2019 (majority in January) PECO - Pennsylvania (Natural Gas) $ 4 (a) July 1, 2018 Not applicable BGE - Maryland (Electric) $ 72 January 31, 2018 February 1, 2018 January 1, 2018 - January 31, 2018 To be addressed in next electric distribution base rate case BGE - Maryland (Natural Gas) $ 31 January 31, 2018 February 1, 2018 January 1, 2018 - January 31, 2018 January 4, 2019 $2 / Q1 2019 Pepco - Maryland (Electric) $ 31 May 31, 2018 June 1, 2018 January 1, 2018 - June 1, 2018 May 31, 2018 $10 / July 2018 Pepco - District of Columbia (Electric) $ 39 August 9, 2018 August 13, 2018 January 1, 2018 - August 12, 2018 September 7, 2018 $20 / September 2018 DPL - Maryland (Electric) $ 14 April 18, 2018 April 20, 2018 January 1, 2018 - March 31, 2018 April 18, 2018 $2 / June 2018 DPL - Delaware (Electric) $ 19 August 21, 2018 March 17, 2018 February 1, 2018 - March 17, 2018 August 21, 2018 $3 / Q4 2018 DPL - Delaware (Natural Gas) $ 7 November 8, 2018 March 17, 2018 February 1, 2018 - March 17, 2018 November 8, 2018 $1 / Q4 2018 ACE - New Jersey (Electric) $ 23 August 29, 2018 September 8, 2018 January 1, 2018 - June 30, 2018 August 29, 2018 $6 / Q4 2018 __________ (a) On May 17, 2018, the PAPUC issued an order directing Pennsylvania utility companies without an existing base rate case, including PECO’s gas distribution business, to start passing back the savings from January 1, 2018 onward through a negative surcharge mechanism to be effective on July 1, 2018. Pursuant to that order, PECO filed a negative surcharge mechanism and began on July 1, 2018, to return the estimated annual 2018 tax savings above to its natural gas distribution customers. As discussed above, ComEd’s, BGE’s, Pepco’s, DPL’s and ACE’s transmission formula rates currently do not provide for the pass back or recovery of income tax-related regulatory liabilities or assets, including those established upon enactment of the TCJA. On December 13, 2016 (as amended on March 13, 2017) and on February 23, 2018 (as amended on July 9, 2018), BGE and ComEd, Pepco, DPL and ACE, respectively, each filed with FERC to revise their transmission formula rate mechanisms to provide for pass back and recovery of transmission-related income tax-related regulatory liabilities and assets, including those established upon enactment of the TCJA. See discussion below for additional information regarding these filings. See Note 14 - Income Taxes for additional information on Corporate Tax Reform. Other State Regulatory Matters Illinois Regulatory Matters Energy Efficiency Formula Rate (Exelon and ComEd). FEJA allows ComEd to defer energy efficiency costs (except for any voltage optimization costs which are recovered through the electric distribution formula rate) as a separate regulatory asset that is recovered through the energy efficiency formula rate over the weighted average useful life, as approved by the ICC, of the related energy efficiency measures. ComEd earns a return on the energy efficiency regulatory asset at a rate equal to its weighted average cost of capital, which is based on a year-end capital structure and calculated using the same methodology applicable to ComEd’s electric distribution formula rate. Beginning January 1, 2018 through December 31, 2030, the return on equity that ComEd earns on its energy efficiency regulatory asset is subject to a maximum downward or upward adjustment of 200 basis points if ComEd’s cumulative persisting annual MWh savings falls short of or exceeds specified percentage benchmarks of its annual incremental savings goal. ComEd is required to file an update to its energy efficiency formula rate on or before June 1 st each year, with resulting rates effective in January of the following year. The annual update is based on projected current year energy efficiency costs, PJM capacity revenues, and the projected year-end regulatory asset balance less any related deferred income taxes (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect for the prior year and actual costs incurred from the year (annual reconciliation). The approved energy efficiency formula rate also provides for revenue decoupling provisions similar to those in ComEd’s electric distribution formula rate. During 2018, the ICC approved the following total increases in ComEd's requested energy efficiency revenue requirement: Filing Date Requested Revenue Requirement Increase Approved Revenue Requirement Increase Approved ROE Approval Date Rate Effective Date June 1, 2018 $ 39 $ 42 (a) 8.69 % December 4, 2018 January 1, 2019 _________ (a) ComEd’s 2018 approved revenue requirement above reflects an increase of $41 million for the initial year revenue requirement for 2018 and 2019 and an increase of $1 million related to the annual reconciliation for 2017. The revenue requirement for 2018 and 2019 and the annual reconciliation for 2017 provides for a weighted average debt and equity return on distribution rate base of 6.52% inclusive of an allowed ROE of 8.69% , reflecting the average rate on 30-year treasury notes plus 580 basis points. See table below for ComEd's regulatory assets associated with its energy efficiency formula rate. Maryland Regulatory Matters Cash Working Capital Order (Exelon and BGE). On November 17, 2016, the MDPSC rendered a decision in the proceeding to review BGE’s request to recover its cash working capital (CWC) requirement for its Provider of Last Resort service, also known as Standard Offer Service (SOS), as well as other components that make up the Administrative Charge, the mechanism that enables BGE to recover its SOS-related costs. The Administrative Charge is comprised of five components: CWC, uncollectibles, incremental costs, return, and an administrative adjustment, which acts as a proxy for retail suppliers’ costs. The Commission accepted BGE's positions on recovery of CWC and pass-through recovery of BGE’s actual uncollectibles and incremental costs. The order also grants BGE a return on the SOS. The Commission ruled that the level of the administrative adjustment will be determined in BGE’s next rate case. Subsequently, the MDPSC Staff and residential consumer advocate sought clarification and appealed the amount of return awarded to BGE on the SOS. The appeal currently resides with the Maryland Court of Special Appeals. BGE cannot predict the outcome of this appeal. Smart Meter and Smart Grid Investments (Exelon and BGE). In August 2010, the MDPSC approved a comprehensive smart grid initiative for BGE that included the planned installation of 2 million residential and commercial electric and natural gas smart meters at an expected total cost of $480 million of which $200 million was funded by SGIG. The MDPSC’s approval ordered BGE to defer the associated incremental costs, depreciation and amortization, and an appropriate return, in a regulatory asset until such time as a cost-effective advanced metering system is implemented. See AMI programs in the Regulatory Assets and Liabilities section below for additional information. As part of the 2015 electric and natural gas distribution rate case filed on November 6, 2015, BGE sought recovery of its smart grid initiative costs, supported by evidence demonstrating that BGE had, in fact, implemented a cost-beneficial advanced metering system. On June 3, 2016, the MDPSC issued an order concluding that the smart grid initiative overall is cost beneficial to its customers. However, the June 3 rd order contained several cost disallowances and adjustments including disallowances of certain program and meter installation costs and denial of recovery of any return on unrecovered costs for non-AMI meters replaced under the program. BGE and the residential consumer advocate subsequently both filed a petition for rehearing of the June 3 rd order. On July 29, 2016, the MDPSC issued an order on the petitions for rehearing that reversed certain of its prior cost disallowances and adjustments related to the smart grid initiative. As a combined result of the MDPSC orders in BGE's 2015 electric and natural gas distribution base rate case, BGE recorded a $52 million charge in June 2016 to Operating and maintenance expense in Exelon’s and BGE’s Consolidated Statements of Operations and Comprehensive Income reducing certain regulatory assets and other long-lived assets and reclassified $56 million of legacy meter costs from Property, plant and equipment, net to Regulatory assets in Exelon's and BGE's Consolidated Balance Sheets. In BGE’s 2018 natural gas distribution base rate case, the MDPSC allowed BGE to recover the gas portion of the post-test year regulatory asset, including a return thereon, over three years. The electric portion of the same regulatory asset will be addressed in BGE’s next electric distribution base rate case. The Maryland Strategic Infrastructure Development and Enhancement Program (Exelon and BGE). In 2013, legislation in Maryland was signed into law to establish a mechanism, separate from base rate proceedings, for gas companies to promptly recover reasonable and prudent costs of eligible infrastructure replacement projects incurred after June 1, 2013. The monthly surcharge and infrastructure replacement costs must be approved by the MDPSC and are subject to a cap and require an annual true-up of the surcharge revenues against actual expenditures. Investment levels in excess of the cap would be recoverable in a subsequent gas base rate proceeding at which time all costs for the infrastructure replacement projects would be rolled into gas distribution base rates. Irrespective of the cap, BGE is required to file a gas rate case every five years under this legislation. On December 1, 2017 (as amended on January 22, 2018), BGE filed an application with the MDPSC seeking approval for a new gas infrastructure replacement plan and associated surcharge, effective for the five-year period from 2019 through 2023. On May 30, 2018, the MDPSC approved with modifications a new infrastructure plan and associated surcharge, subject to BGE's acceptance of the Order. On June 1, 2018, BGE accepted the MDPSC Order and the associated surcharge will be effective in rates beginning in January 2019. The new five-year plan calls for capital expenditures over the 2019-2023 timeframe of $732 million, with an associated revenue requirement of $200 million. District of Columbia Regulatory Matters District of Columbia Power Line Undergrounding Initiative (Exelon, PHI and Pepco). The District of Columbia government enacted on a permanent basis (effective July 11, 2017) legislation to amend the Electric Company Infrastructure Improvement Financing Act of 2014 (as amended) (the Infrastructure Improvement Financing Act) to authorize the District of Columbia Power Line Undergrounding (DC PLUG) initiative, a projected six year, $500 million project to place underground some of the District of Columbia’s most outage-prone power lines with $250 million of the project costs funded by Pepco and $250 million funded by the District of Columbia. The $250 million of project costs funded by Pepco will earn a return and be recovered through a volumetric surcharge on the electric bill of Pepco's customers in the District of Columbia. The $250 million of project costs funded by the District of Columbia will come from two sources. Project costs of $187.5 million will be funded through a charge assessed on Pepco by the District of Columbia; Pepco will recover this charge from customers through a volumetric distribution rider. The remaining costs up to $62.5 million are to be funded by the existing capital projects program of the District Department of Transportation (DDOT). Ownership and responsibility for the operation and maintenance of assets funded by the District of Columbia will be transferred to Pepco for a nominal amount upon completion, and Pepco will not recover or earn a return on the cost of these assets. In accordance with the Infrastructure Improvement Financing Act, Pepco filed an application for approval of the first two-year plan in the DC PLUG initiative (the First Biennial Plan) on July 3, 2017. Pepco will then be required to make two additional applications. On November 9, 2017, the DCPSC issued an order approving the First Biennial Plan and the application for a financing order. Pursuant to that order, Pepco is obligated to pay $187.5 million to the District of Columbia over the six-year project term, of which it expects to pay $30 million in 2019. Pepco recorded an obligation and offsetting regulatory asset in November. Rates for the DC PLUG initiative went into effect on February 7, 2018. New Jersey Regulatory Matters ACE Infrastructure Investment Program Filing (Exelon, PHI and ACE). On February 28, 2018, ACE filed with the NJBPU the company’s Infrastructure Investment Program (IIP) proposing to seek recovery of a series of investments through a new rider mechanism, totaling $338 million , between 2019-2022 to provide safe and reliable service for its customers. The IIP will allow for more timely recovery of investments made to modernize and enhance ACE’s electric system. ACE currently expects a decision in this matter in the second quarter of 2019 but cannot predict if the NJBPU will approve the application as filed. New Jersey Consolidated Tax Adjustment (Exelon, PHI and ACE). The Consolidated Tax Adjustment (CTA) is a ratemaking policy that requires utilities that are part of a consolidated tax group to share with customers the tax benefits that came from losses at unregulated affiliates through a reduction in rate base. After opening a generic proceeding to review the policy, in 2014, the NJBPU issued a decision which retained the CTA, but in a modified format that significantly reduced the impact of the CTA to ACE. On September 18, 2017, the Appellate Division of the Superior Court of New Jersey reversed the NJBPU’s decision in adopting the revised CTA policy and held that NJBPU’s actions related to the CTA constituted a rulemaking that should have been undertaken pursuant to the requirements of the Administrative Procedures Act. The Court did not address the merits of the CTA methodology itself. The NJBPU issued a proposed rule for comment, consistent with the requirements of the Administrative Procedures Act. On January 17, 2019, the NJBPU adopted the proposed CTA regulations, which do not have a material impact on ACE. The CTA regulations will be sent to the Office of Administrative Law for publication in the New Jersey Register, which is expected on or before March 4, 2019. New Jersey Clean Energy Legislation (Exelon and ACE). On May 23, 2018, the Governor of New Jersey signed new legislation, effective immediately, that established and modified New Jersey’s clean energy and energy efficiency programs and solar and renewable energy portfolio standards. The new legislation expands the state's renewable portfolio standard to require that 50% of electric generation sold be from renewable energy sources by 2030; modifies the New Jersey solar renewable energy portfolio standard to require that 5.1% of electric generation sold in New Jersey be from solar electric power by 2021; lowers the solar alternative compliance payment amount starting in 2019 and requires the NJBPU to adopt rules to replace the current solar renewable energy credit program; and requires the NJBPU to increase its offshore wind energy credit program to 3,500 MW. The new legislation further imposes an energy efficiency standard that each electric public utility will be required to reduce annual usage by 2% and provides for utilities to annually file for recovery of the costs of the programs, including the revenue impact of sales losses resulting from the programs. The NJBPU is required to initiate a study to determine the savings targets for each public utility, to adopt other rules regarding the programs, and to approve energy efficiency and peak demand reduction programs for each utility. The new legislation also requires the NJBPU to conduct an energy storage analysis including the potential costs and benefits and to initiate a proceeding to establish a goal of achieving 2,000 MW of energy storage by 2030; requires the utilities to conduct a study on voltage optimization on their distribution system; and requires the NJBPU to establish a community solar program to permit customers to participate in a solar project that is not located on the customer’s property which the NJBPU issued regulations on January 17, 2019. On the same day, the Governor of New Jersey also signed new legislation, effective immediately, that will establish a ZEC program providing compensation for nuclear plants that demonstrate to the NJBPU that they meet certain requirements, including that they make a significant contribution to air quality in the state and that their revenues are insufficient to cover their costs and risks. Electric distribution utilities in New Jersey, including ACE, will be authorized to collect from retail distribution customers through a non-bypassable charge all costs associated with the utility’s procurement of the ZECs. See Generation Regulatory Matters below for additional information. Other Federal Regulatory Matters Transmission-Related Income Tax Regulatory Assets (Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE). On December 13, 2016 (as amended on March 13, 2017), BGE filed with FERC to begin recovering certain existing and future transmission-related income tax regulatory assets through its transmission formula rate. BGE’s existing regulatory assets included (1) amounts that, if BGE’s transmission formula rate provided for recovery, would have been previously amortized and (2) amounts that would be amortized and recovered prospectively. ComEd, Pepco, DPL and ACE had similar transmission-related income tax regulatory liabilities and assets also requiring FERC approval. On November 16, 2017, FERC issued an order rejecting BGE’s proposed revisions to its transmission formula rate to recover these transmission-related income tax regulatory assets. FERC’s rejection order focused on the lack of timeliness of BGE’s request to recover amounts that would have been previously amortized but indicated that ongoing recovery of certain transmission-related income tax regulatory assets would provide for a more accurate revenue requirement. Based on FERC’s order, management of each company concluded that the portion of the total transmission-related income tax regulatory assets that would have been previously amortized and recovered through rates had the transmission formula rate provided for such recovery was no longer probable of recovery. As a result, Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE recorded the following charges to Income tax expense within their Consolidated Statements of Operations and Comprehensive Income in the fourth quarter of 2017, reducing their associated transmission-related income tax regulatory assets. Similar regulatory assets and liabilities at PECO are not subject to the same FERC transmission rate recovery formula and, thus, are not impacted by BGE’s November 16, 2017 FERC order. See above for additional information regarding PECO's transmission formula rate filing. For the year ended December 31, 2017 Exelon $ 35 ComEd 3 BGE 5 PHI 27 Pepco 14 DPL 6 ACE 7 On December 18, 2017, BGE filed for clarification and rehearing of FERC’s order, still seeking full recovery of its existing transmission-related income tax regulatory asset amounts, including those amounts that would have been previously amortized and recovered through rates had the transmission formula rate provided for such recovery. On February 27, 2018 (and updated on March 26, 2018), BGE submitted a letter to FERC advising that the lower federal corporate income tax rate effective January 1, 2018 provided for in the TCJA will be reflected in BGE’s annual formula rate update effective June 1, 2018, but that the deferred income tax benefits will not be passed back to customers unless BGE’s formula rate is revised to provide for pass back and recovery of transmission-related income tax-related regulatory liabilities and assets. On February 23, 2018 (as amended on July 9, 2018), ComEd, Pepco, DPL, and ACE each filed with FERC to revise their transmission formula rate mechanisms to facilitate passing back to customers ongoing annual TCJA tax savings and to permit recovery of transmission-related income tax regulatory assets, including those amounts that would have been previously amortized and recovered through rates had the transmission formula rate provided for such recovery. On September 7, 2018, FERC issued orders rejecting BGE’s December 18, 2017 request for rehearing and clarification and ComEd's, Pepco's, DPL's and ACE's February 23, 2018 (as amended on July 9, 2018) filings, again citing the lack of timeliness of the requests to recover amounts that would have been previously amortized, but indicating that ongoing recovery of certain transmission-related income tax regulatory assets would provide for a more accurate revenue requirement. The orders did not address the remittance of TCJA transmission-related income tax regulatory liabilities, but rather referenced FERC’s separate Notice of Inquiry of such amounts issued on March 15, 2018. On October 1, 2018, ComEd, BGE, Pepco, DPL, and ACE submitted new filings to recover ongoing non-TCJA amortization amounts and refund TCJA transmission-related income tax regulatory liabilities for the prospective period starting on October 1, 2018. FERC issued deficiency letters requesting additional information on November 21, 2018 and January 28, 2019. ComEd, BGE, Pepco, DPL, and ACE responded to the November 21, 2018 deficiency letter on November 29, 2018 but cannot predict the outcome of these FERC proceedings. If FERC ultimately rules that the future, ongoing non-TCJA amortization amounts are not recoverable, Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE woul |
Mergers, Acquisitions and Dispo
Mergers, Acquisitions and Dispositions (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Business Combinations [Abstract] | |
Mergers, Acquisitions and Dispositions | Mergers, Acquisitions and Dispositions (Exelon, Generation and PHI) Acquisition of FirstEnergy Solutions Load Business (Exelon and Generation) On July 9, 2018, Generation entered into an Asset Purchase Agreement (the Purchase Agreement) with FirstEnergy Solutions Corporation (FirstEnergy). Pursuant to the Purchase Agreement, FirstEnergy agreed to assign all of its retail electricity and wholesale load serving contracts and certain other related commodity contracts to Generation for an all cash purchase price of $140 million . The closing of the transaction was subject to certain conditions including the approval of the Purchase Agreement by the United States Bankruptcy Court for the Northern District of Ohio (Bankruptcy Court). At FirstEnergy's request, Bankruptcy Court's review of the transaction was delayed on six occasions, and Generation disputed these delays with the Bankruptcy Court. On January 23, 2019 the Bankruptcy Court approved an order that stipulated FirstEnergy's termination of the Purchase Agreement, effective January 22, 2019. The termination order provided for Generation to receive a refund of its escrow deposit, payment of a termination fee and reimbursement of transaction expenses, all of which were immaterial. Acquisition of James A. FitzPatrick Nuclear Generating Station (Exelon and Generation) On March 31, 2017, Generation acquired the 842 MW single-unit James A. FitzPatrick (FitzPatrick) nuclear generating station located in Scriba, New York from Entergy Nuclear FitzPatrick LLC (Entergy) for a total purchase price of $289 million , which consisted of a cash purchase price of $110 million and a net cost reimbursement to and on behalf of Entergy of $179 million . As part of the acquisition agreements, Generation provided nuclear fuel and reimbursed Entergy for incremental costs to prepare for and conduct a plant refueling outage; and Generation reimbursed Entergy for incremental costs to operate and maintain the plant for the period after the refueling outage through the acquisition closing date. These reimbursements covered costs that Entergy otherwise would have avoided had it shutdown the plant as originally intended in January 2017. The amounts reimbursed by Generation were offset by FitzPatrick's electricity and capacity sales revenues for this same post-outage period. As part of the transaction, Generation received the FitzPatrick NDT fund assets and assumed the obligation to decommission FitzPatrick. The NRC license for FitzPatrick expires in 2034. The fair values of FitzPatrick’s assets and liabilities were determined based on significant estimates and assumptions that are judgmental in nature, including projected future cash flows (including timing), discount rates reflecting risk inherent in the future cash flows and future power and fuel market prices. An after-tax bargain purchase gain of $233 million was included within Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income which primarily reflects differences in strategies between Generation and Entergy for the intended use and ultimate decommissioning of the plant. See Note 15 — Asset Retirement Obligations and Note 16 — Retirement Benefits for additional information regarding the FitzPatrick decommissioning ARO and pension and OPEB updates. The following table summarizes the final acquisition-date fair value of the consideration transferred and the assets and liabilities assumed for the FitzPatrick acquisition by Generation: Cash paid for purchase price $ 110 Cash paid for net cost reimbursement 125 Nuclear fuel transfer 54 Total consideration transferred $ 289 Identifiable assets acquired and liabilities assumed Current assets $ 60 Property, plant and equipment 298 Nuclear decommissioning trust funds 807 Other assets (a) 114 Total assets $ 1,279 Current liabilities $ 6 Nuclear decommissioning ARO 444 Pension and OPEB obligations 33 Deferred income taxes 149 Spent nuclear fuel obligation 110 Other liabilities 15 Total liabilities $ 757 Total net identifiable assets, at fair value $ 522 Bargain purchase gain (after-tax) $ 233 _________ (a) Includes a $110 million asset associated with a contractual right to reimbursement from the New York Power Authority (NYPA), a prior owner of FitzPatrick, associated with the DOE one-time fee obligation. See Note 22 - Commitments and Contingencies for additional information regarding SNF obligations to the DOE. Exelon and Generation incurred $57 million of merger and integration related costs to FitzPatrick for the year ended December 31, 2017 which are included within Operating and maintenance expense in Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. Exelon and Generation did not incur any merger and integration costs related to FitzPatrick for the year ended December 31, 2018 . Acquisition of ConEdison Solutions (Exelon and Generation) On September 1, 2016, Generation acquired the competitive retail electricity and natural gas business of Consolidated Edison Solutions, Inc. (ConEdison Solutions), a subsidiary of Consolidated Edison, Inc. for a purchase price of $257 million including net working capital of $204 million . The renewable energy, sustainable services and energy efficiency businesses of ConEdison Solutions are excluded from the transaction. The purchase price of $257 million equaled the estimated fair value of the net assets acquired and the liabilities assumed and, therefore, no goodwill or bargain purchase was recorded as of the acquisition date. Merger with Pepco Holdings, Inc. (Exelon) Description of Transaction On March 23, 2016 , Exelon completed the merger contemplated by the Merger Agreement among Exelon, Purple Acquisition Corp., a wholly owned subsidiary of Exelon (Merger Sub) and Pepco Holdings, Inc. (PHI), for a total purchase price consideration of approximately $7.1 billion . As a result of the merger, Merger Sub was merged into PHI (the PHI Merger) with PHI surviving as a wholly owned subsidiary of Exelon and Exelon Energy Delivery Company, LLC (EEDC), a wholly owned subsidiary of Exelon which also owns Exelon's interests in ComEd, PECO and BGE (through a special purpose subsidiary in the case of BGE). Following the completion of the PHI Merger, Exelon and PHI completed a series of internal corporate organization restructuring transactions resulting in the transfer of PHI’s unregulated business interests to Exelon and Generation and the transfer of PHI, Pepco, DPL and ACE to a special purpose subsidiary of EEDC. Regulatory Matters Approval of the merger in Delaware, New Jersey, Maryland and the District of Columbia was conditioned upon Exelon and PHI agreeing to certain commitments including where applicable: customer rate credits, funding for energy efficiency and delivery system modernization programs, a green sustainability fund, workforce development initiatives, charitable contributions, renewable generation and other required commitments. In addition, the orders approving the merger in Delaware, New Jersey and Maryland include a “most favored nation” provision which, generally, requires allocation of merger benefits proportionally across all the jurisdictions. Total nominal cost of commitments was $513 million excluding renewable generation commitments (approximately $444 million on a net present value basis amount, excluding renewable generation commitments and charitable contributions). During the fourth quarter of 2018, Exelon finalized the application of $5 million funding for residential and non-residential customers in the DPL Maryland service territory. This resulted in an adjustment to merger commitment costs recorded at Exelon Corporate and DPL. Exelon Corporate recorded a decrease of $5 million and DPL recorded an increase of $5 million in Operating and maintenance expense. The following amounts represent total commitment costs for Exelon, PHI, Pepco, DPL and ACE that have been recorded since the merger date: Expected Payment Period Successor Description Exelon PHI Pepco DPL ACE Rate credits 2016 - 2021 $ 259 $ 264 $ 91 $ 72 $ 101 Energy efficiency 2016 - 2021 117 — — — — Charitable contributions 2016 - 2026 50 50 28 12 10 Delivery system modernization Q2 2017 22 — — — — Green sustainability fund Q2 2017 14 — — — — Workforce development 2016 - 2020 17 — — — — Other 29 6 1 5 — Total commitments $ 508 $ 320 $ 120 $ 89 $ 111 Remaining commitments as of December 31, 2018 $ 128 $ 92 $ 73 $ 12 $ 7 Pursuant to the orders approving the merger, Exelon made $73 million , $46 million and $49 million of equity contributions to Pepco, DPL and ACE, respectively, in the second quarter of 2016 to fund the after-tax amounts of the customer bill credit and the customer base rate credit commitments. In addition, Exelon is committed to develop or to assist in the commercial development of approximately 37 MWs of new solar generation in Maryland, District of Columbia and Delaware, at an estimated cost of approximately $127 million , which will generate future earnings at Exelon and Generation. Investment costs, which are expected to be primarily capital in nature, will be recognized as incurred and recorded on Exelon's and Generation's financial statements. As of December 31, 2018, 27 MWs were developed and Exelon and Generation have incurred costs of $83 million . Exelon has also committed to purchase 100 MWs of wind energy in PJM. DPL has committed to conducting three RFPs to procure up to a total of 120 MWs of wind RECs for the purpose of meeting Delaware's renewable portfolio standards. DPL has conducted two of the three wind REC RFPs. The first 40 MW wind REC tranche was conducted in 2017 and did not result in a purchase agreement. The second 40 MW wind REC tranche was conducted in 2018 and resulted in a proposed REC purchase agreement that is pending review and approval with the DPSC. The third and final 40 MW wind REC tranche will be conducted in 2022. Pursuant to the various jurisdictions' merger approval conditions, over specified periods Pepco, DPL and ACE are not permitted to reduce employment levels due to involuntary attrition associated with the merger integration process and have made other commitments regarding hiring and relocation of positions. In July 2015, the OPC, Public Citizen, Inc., the Sierra Club and the Chesapeake Climate Action Network (CCAN) filed motions to stay the MDPSC order approving the merger. The Circuit Court judge issued an order denying the motions for stay on August 12, 2015. On January 8, 2016, the Circuit Court judge affirmed the MDPSC’s order approving the merger and denied the petitions for judicial review filed by the OPC, the Sierra Club, CCAN and Public Citizen, Inc. On January 19, 2016, the OPC filed a notice of appeal to the Maryland Court of Special Appeals, and on January 21, the Sierra Club and CCAN filed notices of appeal. On January 27, 2017, the Maryland Court of Special Appeals affirmed the Circuit Court's judgment that the MDPSC did not err in approving the merger. The OPC and Sierra Club filed petitions seeking further review in the Maryland Court of Appeals, which is the highest court in Maryland. On August 29, 2018, the Maryland Court of Appeals affirmed the MDPSC's May 2015 Order approving the merger of Exelon and PHI. Between March 25, 2016 and April 22, 2016, various parties filed motions with the DCPSC to reconsider its March 23, 2016 order approving the merger. On June 17, 2016, the DCPSC denied all motions. In August 2016, the District Legal Entity of Columbia Office of People’s Counsel, the District of Columbia Government, and Public Citizen jointly with DC Sun each filed petitions for judicial review of the DCPSC’s March 23, 2016 order with the District of Columbia Court of Appeals. On July 20, 2017, the Court issued an opinion rejecting all of appellants’ arguments and affirming the Commission’s decision approving the merger. Accounting for the Merger Transaction The total purchase price consideration for the PHI merger was approximately $7.1 billion . The excess of the purchase price over the estimated fair value of the assets acquired and the liabilities assumed totaled $4 billion , which was recognized as goodwill by PHI and Exelon at the merger date, reflecting the value associated with enhancing Exelon's regulated utility portfolio of businesses, including the ability to leverage experience and best practices across the utilities and the opportunities for synergies. None of this goodwill is expected to be tax deductible. For purposes of future required impairment assessments, the goodwill has been assigned to PHI's reportable units Pepco, DPL and ACE. See Note 10 - Intangible Assets for additional information. Immediately following closing of the merger, $235 million of net assets associated with PHI's unregulated business interests were distributed by PHI to Exelon. Exelon contributed $163 million of such net assets to Generation. Rates charged to customers are established by a regulator to provide for recovery of costs and a fair return on invested capital, or rate base, generally measured at historical cost. Historical cost information therefore is the most relevant presentation for the financial statements of PHI’s rate regulated utility subsidiary registrants, Pepco, DPL and ACE. As such, Exelon and PHI did not push-down the application of acquisition accounting to PHI's utility registrants, and therefore the financial statements of Pepco, DPL and ACE do not reflect the revaluation of any assets and liabilities. The current impact of PHI, including its unregulated businesses, in Exelon's Consolidated Statements of Operations and Comprehensive Income includes Operating revenues and Net Income (Loss) as follows: For the Years Ended December 31, 2018 2017 2016 Operating Revenues 4,670 4,829 3,785 Net Income (Loss) 453 364 (66 ) For the periods ended December 31, 2018 , 2017 and 2016 , the Registrants have recognized costs to achieve the PHI merger as follows: For the Year Ended December 31, Acquisition, Integration and Financing Costs (a) 2018 2017 2016 Exelon $ 7 $ 16 $ 143 Generation 5 22 37 ComEd (b) — 1 (6 ) PECO 1 4 5 BGE (b) 1 4 (1 ) Pepco (b) — (6 ) 28 DPL (b) — (7 ) 20 ACE (b) — (6 ) 19 Successor Predecessor For the Year Ended December 31, March 24, 2016 to December 31, 2016 January 1, 2016 to Acquisition, Integration and Financing Costs (a) 2018 2017 PHI (b) $ — $ (18 ) $ 69 $ 29 ______________ (a) The costs incurred are classified primarily within Operating and maintenance expense in the Registrants’ respective Consolidated Statements of Operations and Comprehensive Income, with the exception of the financing costs, which are included within Interest expense. Costs do not include merger commitments discussed above. (b) For the year ended December 31, 2017 , includes deferrals of previously incurred integration costs as regulatory assets of $24 million , $8 million , $8 million , and $8 million at PHI, Pepco, DPL and ACE, respectively. For the year ended December 31, 2016 , includes deferrals of previously incurred integration costs as regulatory assets of $8 million , $6 million , $11 million and $4 million at ComEd, BGE, Pepco and DPL, respectively. For the Successor period March 24, 2016 to December 31, 2016 , includes deferrals of previously incurred integration costs as regulatory assets of $16 million at PHI. See Note 4 - Regulatory Matters for additional information. Pro-forma Impact of the Merger The following unaudited pro-forma financial information reflects the consolidated results of operations of Exelon as if the PHI merger had taken place on January 1, 2015 . The unaudited pro forma information was calculated after applying Exelon’s accounting policies and adjusting PHI’s results to reflect purchase accounting adjustments. The unaudited pro-forma financial information has been presented for illustrative purposes only and is not necessarily indicative of results of operations that would have been achieved had the merger events taken place on the dates indicated, or future consolidated results of operations of the combined company. Year Ended December 31, 2016 (a) 2015 (b) Total operating revenues $ 32,342 $ 33,823 Net income attributable to common shareholders 1,562 2,618 Basic earnings per share $ 1.69 $ 2.85 Diluted earnings per share 1.69 2.84 ______________ (a) The amounts above exclude non-recurring costs directly related to the merger of $680 million and intercompany revenue of $171 million for the year ended December 31, 2016 . (b) The amounts above exclude non-recurring costs directly related to the merger of $92 million and intercompany revenue of $559 million for the year ended December 31, 2015 . Disposition of Oyster Creek (Exelon and Generation) On July 31, 2018, Generation entered into an agreement with Holtec International (Holtec) and its indirect wholly owned subsidiary, Oyster Creek Environmental Protection, LLC (OCEP), for the sale and decommissioning of the Oyster Creek Generating Station (Oyster Creek) located in Forked River, New Jersey. On September 17, 2018, Oyster Creek permanently ceased generation operations. Under the terms of the transaction, Generation will transfer to OCEP substantially all the assets associated with Oyster Creek, including assets held in NDT funds, along with the assumption of liability for all responsibility for the site, including full decommissioning and ongoing management of spent fuel until the spent fuel is moved offsite. In addition to the assumption of liability for the full decommissioning and ongoing management of spent fuel, other consideration to be received in the transaction is contingent on several factors, including a requirement that Generation deliver a minimum NDT fund balance at closing, subject to adjustment for specific terms that include income taxes that would be imposed on any net unrealized built-in gains and certain decommissioning activities to be performed during the pre-close period after the unit shuts down in the fall of 2018 and prior to the anticipated close of the transaction. The terms of the transaction also include various forms of performance assurance for the obligations of OCEP to timely complete the required decommissioning, including a parental guaranty from Holtec for all performance and payment obligations of OCEP, and a requirement for Holtec to deliver a letter of credit to Generation upon the occurrence of specified events. As a result of the transaction, in 2018, Exelon and Generation reclassified certain Oyster Creek assets and liabilities in Exelon’s and Generation’s Consolidated Balance Sheets as held for sale at their respective fair values. At December 31, 2018 Generation has $897 million and $777 million of Assets held for sale and Liabilities held for sale, respectively, for Oyster Creek. Upon remeasurement of the Oyster Creek ARO in 2018, Exelon and Generation recognized an $84 million pre-tax charge to Operating and maintenance expense. See Note 15 - Asset Retirement Obligations for additional information. Completion of the transaction contemplated by the sale agreement is subject to the satisfaction of several closing conditions, including approval of the license transfer from the NRC and other regulatory approvals, and the receipt of a private letter ruling from the IRS. Generation currently anticipates satisfaction of the closing conditions to occur in the second half of 2019. Disposition of EGTP and Acquisition of Handley Generating Station (Exelon and Generation) EGTP, a Delaware limited liability company, was formed in 2014 with the purpose of financing a portfolio of assets comprised of two combined-cycle gas turbines (CCGTs) and three peaking/simple cycle facilities consisting of approximately 3.4 GW of generation capacity in ERCOT North and Houston Zones. EGTP was an indirect wholly owned subsidiary of Exelon and Generation. EGTP’s operating cash flows were negatively impacted by certain market conditions and the seasonality of its cash flows. On May 2, 2017, as a result of the negative impacts of certain market conditions and the seasonality of its cash flows, EGTP entered into a consent agreement with its lenders to permit EGTP to draw on its revolving credit facility and initiate an orderly sales process to sell the assets of its wholly owned subsidiaries. As a result, Exelon and Generation classified certain of EGTP assets and liabilities as held for sale at their respective fair values less costs to sell and recorded a $460 million pre-tax impairment loss. See Note 13 - Debt and Credit Agreements for details regarding the nonrecourse debt associated with EGTP and Note 7 - Impairment of Long-Lived Assets and Intangibles for additional information. On November 7, 2017, EGTP and all of its wholly owned subsidiaries filed voluntary petitions for relief under Chapter 11 of Title 11 of the United States Code in the United States Bankruptcy Court for the District of Delaware, which resulted in Exelon and Generation deconsolidating EGTP's assets and liabilities from their consolidated financial statements in the fourth quarter of 2017 that resulted in a pre-tax gain upon deconsolidation of $213 million . Concurrently with the Chapter 11 filings, Generation entered into an asset purchase agreement to acquire one of EGTP's generating plants, the Handley Generating Station, subject to a potential adjustment for fuel oil and assumption of certain liabilities. In the Chapter 11 Filings, EGTP requested that the proposed acquisition of the Handley Generating Station be consummated through a court-approved and supervised sales process. The acquisition closed on April 4, 2018 for a purchase price of $62 million . The Chapter 11 bankruptcy proceedings were finalized on April 17, 2018, resulting in the ownership of EGTP assets (other than the Handley Generating Station) being transferred to EGTP's lenders. Other Asset Dispositions (Exelon, Generation, DPL and Pepco) In December 2017, Generation entered into an agreement to sell its interest in an electrical contracting business that primarily installs, maintains and repairs underground and high-voltage cable transmission and distribution systems. As a result, as of December 31, 2017, certain assets and liabilities were classified as held for sale and included in the Other current assets and Other current liabilities balances in Exelon's and Generation's Consolidated Balance Sheet. On February 28, 2018, Generation completed the sale of its interest for $87 million , resulting in a pre-tax gain which is included within Gain on sales of assets and businesses in Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. In June 2018, additional proceeds were received, and a pre-tax gain was recorded within Gain on sales of assets and businesses in Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. During the fourth quarter of 2016, as part of its continual assessment of growth and development opportunities, Generation reevaluated and in certain instances terminated or renegotiated certain projects and contracts. As a result, a pre-tax loss of $69 million was recorded within Loss on sales of assets and businesses and pre-tax impairment charges of $23 million was recorded within Operating and maintenance expense in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. On June 16, 2016, Generation initiated the sales process of its Upstream business by executing a forbearance agreement with the lenders of the nonrecourse debt. See Note 13 - Debt and Credit Agreements for additional information. In December 2016, Generation sold substantially all of the Upstream assets for $37 million which resulted in a pre-tax loss on sale of $10 million which is included in Gain (loss) on sales of assets and businesses in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. |
Property, Plant and Equipment (
Property, Plant and Equipment (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Property, Plant and Equipment [Abstract] | |
Property, Plant and Equipment (All Registrants) | Property, Plant and Equipment (All Registrants) Exelon The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-90 $ 53,090 $ 49,506 Electric—generation 1-56 29,170 29,019 Gas—transportation and distribution 5-90 5,530 5,050 Common—electric and gas 5-75 1,627 1,447 Nuclear fuel (a) 1-8 5,957 6,420 Construction work in progress N/A 3,377 2,825 Other property, plant and equipment (b) 1-50 858 999 Total property, plant and equipment 99,609 95,266 Less: accumulated depreciation (c) 22,902 21,064 Property, plant and equipment, net $ 76,707 $ 74,202 __________ (a) Includes nuclear fuel that is in the fabrication and installation phase of $1,004 million and $1,196 million at December 31, 2018 and 2017 , respectively. (b) Includes Generation’s buildings under capital lease with a net carrying value of $5 million and $7 million at December 31, 2018 and 2017 , respectively. The original cost basis of the buildings was $47 million as of both December 31, 2018 and 2017 , and total accumulated amortization was $42 million and $40 million , as of December 31, 2018 and 2017 , respectively. Also includes ComEd’s buildings under capital lease with a net carrying value at both December 31, 2018 and 2017 of $7 million . The original cost basis of the buildings was $8 million and total accumulated amortization was $1 million as of both December 31, 2018 and 2017 . Includes land held for future use and non-utility property at ComEd, PECO, BGE, Pepco, DPL and ACE of $39 million , $19 million , $25 million , $61 million , $17 million and $28 million , respectively, at December 31, 2018 . (c) Includes accumulated amortization of nuclear fuel in the reactor core at Generation of $2,969 million and $3,159 million as of December 31, 2018 and 2017 , respectively. The following table presents the annual depreciation provisions as a percentage of average service life for each asset category. Average Service Life Percentage by Asset Category 2018 2017 2016 Electric—transmission and distribution 2.73 % 2.75 % 2.73 % Electric—generation (a) 5.37 % 4.36 % 5.94 % Gas 2.07 % 2.10 % 2.17 % Common—electric and gas 6.98 % 7.05 % 7.41 % __________ (a) See Note 8 — Early Plant Retirements for additional information on the accelerated net depreciation and amortization of Clinton, Quad Cities, Oyster Creek and TMI. Generation The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—generation 1-56 $ 29,170 $ 29,019 Nuclear fuel (a) 1-8 5,957 6,420 Construction work in progress N/A 997 838 Other property, plant and equipment (b) 1-8 63 57 Total property, plant and equipment 36,187 36,334 Less: accumulated depreciation (c) 12,206 11,428 Property, plant and equipment, net $ 23,981 $ 24,906 __________ (a) Includes nuclear fuel that is in the fabrication and installation phase of $1,004 million and $1,196 million at December 31, 2018 and 2017 , respectively. (b) Includes buildings under capital lease with a net carrying value of $5 million and $7 million at December 31, 2018 and 2017 , respectively. The original cost basis of the buildings was $47 million as of both December 31, 2018 and 2017 , and total accumulated amortization was $42 million and $40 million , as of December 31, 2018 and 2017 , respectively. (c) Includes accumulated amortization of nuclear fuel in the reactor core of $2,969 million and $3,159 million as of December 31, 2018 and 2017 , respectively. The annual depreciation provisions as a percentage of average service life for electric generation assets were 5.37% , 4.36% and 5.94% for the years ended December 31, 2018 , 2017 and 2016 , respectively. See Note 8 — Early Plant Retirements for additional information on the accelerated depreciation and amortization of Clinton, Quad Cities, Oyster Creek and TMI. License Renewals Depreciation provisions are based on the estimated useful lives of the stations, which reflect the actual renewal of the operating licenses for all of Generation's operating nuclear generating stations except for TMI and Clinton. As a result, the receipt of license renewals has no material impact in the Consolidated Statements of Operations and Comprehensive Income. Beginning in 2017, TMI and Oyster Creek depreciation provisions were based on their 2019 expected shutdown dates. Beginning February 2018, Oyster Creek depreciation provisions were based on its announced shutdown date of September 2018. Clinton depreciation provisions are based on an estimated useful life through 2027 which is the last year of the Illinois Zero Emissions Standard. See Note 4 — Regulatory Matters for additional information regarding license renewals and the Illinois ZECs and Note 8 — Early Plant Retirements for additional information on the impacts of expected and potential early plant retirement. ComEd The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-80 $ 25,991 $ 24,423 Construction work in progress N/A 705 517 Other property, plant and equipment (a), (b) 35-50 46 52 Total property, plant and equipment 26,742 24,992 Less: accumulated depreciation 4,684 4,269 Property, plant and equipment, net $ 22,058 $ 20,723 __________ (a) Includes buildings under capital lease with a net carrying value at both December 31, 2018 and 2017 of $7 million . The original cost basis of the buildings was $8 million and total accumulated amortization was $1 million as of both December 31, 2018 and 2017 . (b) Represents land held for future use and non-utility property. The annual depreciation provisions as a percentage of average service life for electric transmission and distribution assets were 2.95% , 2.99% and 3.03% for the years ended December 31, 2018 , 2017 and 2016 , respectively. PECO The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-65 $ 8,359 $ 7,975 Gas—transportation and distribution 5-70 2,694 2,504 Common—electric and gas 5-50 756 710 Construction work in progress N/A 343 254 Other property, plant and equipment (a) 50 19 21 Total property, plant and equipment 12,171 11,464 Less: accumulated depreciation 3,561 3,411 Property, plant and equipment, net $ 8,610 $ 8,053 __________ (a) Represents land held for future use and non-utility property. The following table presents the annual depreciation provisions as a percentage of average service life for each asset category. Average Service Life Percentage by Asset Category 2018 2017 2016 Electric—transmission and distribution 2.35 % 2.37 % 2.32 % Gas 1.90 % 1.89 % 1.82 % Common—electric and gas 5.44 % 5.47 % 5.11 % BGE The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-90 $ 7,951 $ 7,464 Gas—distribution 5-90 2,630 2,379 Common—electric and gas 5-40 860 771 Construction work in progress N/A 410 367 Other property, plant and equipment (a) 20 25 26 Total property, plant and equipment 11,876 11,007 Less: accumulated depreciation 3,633 3,405 Property, plant and equipment, net $ 8,243 $ 7,602 __________ (a) Represents plant held for future use and non-utility property. The following table presents the annual depreciation provisions as a percentage of average service life for each asset category. Average Service Life Percentage by Asset Category 2018 2017 2016 Electric—transmission and distribution 2.61 % 2.58 % 2.56 % Gas 2.36 % 2.33 % 2.45 % Common—electric and gas 8.50 % 8.64 % 9.45 % PHI The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average 2018 2017 Asset Category Electric—transmission and distribution 5-75 $ 12,664 $ 11,517 Gas—distribution 5-75 486 449 Common—electric and gas 5-75 126 82 Construction work in progress N/A 912 835 Other property, plant and equipment (a) 3-43 99 102 Total property, plant and equipment 14,287 12,985 Less: accumulated depreciation 841 487 Property, plant and equipment, net $ 13,446 $ 12,498 __________ (a) Represents plant held for future use and non-utility property. The following table presents the annual depreciation provisions as a percentage of average service life for each asset category. Average Service Life Percentage by Asset Category 2018 2017 2016 Electric—transmission and distribution 2.61 % 2.63 % 2.52 % Gas 1.59 % 2.07 % 2.57 % Common—electric and gas 6.30 % 6.50 % 8.12 % Pepco The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-75 $ 9,217 $ 8,646 Construction work in progress N/A 536 473 Other property, plant and equipment (a) 25-33 61 59 Total property, plant and equipment 9,814 9,178 Less: accumulated depreciation 3,354 3,177 Property, plant and equipment, net $ 6,460 $ 6,001 __________ (a) Represents plant held for future use and non-utility property. The annual depreciation provisions as a percentage of average service life for electric transmission and distribution assets were 2.40% , 2.35% and 2.17% for the years ended December 31, 2018 , 2017 and 2016 , respectively. DPL The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-70 $ 4,195 $ 3,875 Gas—distribution 5-75 651 614 Common—electric and gas 5-75 136 117 Construction work in progress N/A 151 205 Other property, plant and equipment (a) 10-43 17 15 Total property, plant and equipment 5,150 4,826 Less: accumulated depreciation 1,329 1,247 Property, plant and equipment, net $ 3,821 $ 3,579 __________ (a) Represents plant held for future use and non-utility property. The following table presents the annual depreciation provisions as a percentage of average service life for each asset category. Average Service Life Percentage by Asset Category 2018 2017 2016 Electric—transmission and distribution 2.77 % 2.75 % 2.49 % Gas 1.59 % 2.07 % 2.57 % Common—electric and gas 3.70 % 4.14 % 4.99 % ACE The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-60 $ 3,866 $ 3,607 Construction work in progress N/A 209 138 Other property, plant and equipment (a) 13-15 28 27 Total property, plant and equipment 4,103 3,772 Less: accumulated depreciation 1,137 1,066 Property, plant and equipment, net $ 2,966 $ 2,706 __________ (a) Represents plant held for future use and non-utility property. The annual depreciation provisions as a percentage of average service life for electric transmission and distribution assets were 2.45% , 2.46% and 2.45% for the years ended December 31, 2018 , 2017 and 2016 , respectively. Capitalized Software Costs (All Registrants) The following tables presents net unamortized capitalized software costs and amortization of capitalized software costs by year. Net unamortized software costs Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE December 31, 2018 $ 810 $ 164 $ 206 $ 98 $ 166 $ 165 $ 26 $ 21 $ 14 December 31, 2017 834 173 227 111 179 133 2 1 1 Amortization of capitalized software costs Exelon Generation ComEd PECO BGE Pepco DPL ACE 2018 $ 282 $ 78 $ 79 $ 37 $ 48 $ 2 $ 2 $ 1 2017 270 73 73 39 46 — — — 2016 255 72 62 33 44 — — — Successor Predecessor PHI For the year ended December 31, 2018 For the year ended December 31, 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Amortization of capitalized software costs $ 33 $ 34 $ 29 $ 8 Capitalized Interest and AFUDC (All Registrants) The following table summarizes total incurred interest, capitalized interest and credits to AFUDC by year: Exelon Generation ComEd PECO BGE Pepco DPL ACE 2018 Total incurred interest (a) $ 1,695 $ 464 $ 377 $ 141 $ 130 $ 162 $ 62 $ 68 Capitalized interest 31 31 — — — — — — Credits to AFUDC debt and equity 109 — 30 12 24 34 4 4 2017 Total incurred interest (a) $ 1,658 $ 502 $ 369 $ 130 $ 111 $ 133 $ 54 $ 64 Capitalized interest 63 63 — — — — — — Credits to AFUDC debt and equity 108 — 20 12 22 34 10 9 2016 Total incurred interest (a) $ 1,678 $ 472 $ 469 $ 127 $ 114 $ 137 $ 52 $ 65 Capitalized interest 108 107 — — — — — — Credits to AFUDC debt and equity 98 — 22 11 30 29 7 9 Successor Predecessor PHI For the year ended December 31, 2018 For the year ended December 31, 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Total incurred interest (a) $ 305 $ 263 $ 207 $ 68 Credits to AFUDC debt and equity 44 54 35 10 __________ (a) Includes interest expense to affiliates. See Note 1 — Significant Accounting Policies for additional information regarding property, plant and equipment policies. See Note 13 — Debt and Credit Agreements for additional information regarding Exelon’s, ComEd’s and PECO’s property, plant and equipment subject to mortgage liens. |
Impairment of Long-lived Assets
Impairment of Long-lived Assets (Exelon and Generation) | 12 Months Ended |
Dec. 31, 2018 | |
Impairment or Disposal of Tangible Assets Disclosure [Abstract] | |
Impairment Of Long-Lived Assets (Exelon and Generation) | (Exelon, Generation and PHI) Long-Lived Assets (Exelon, Generation and PHI) Registrants evaluate long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. In the second quarter of 2018, updates to Exelon's long-term view of energy and capacity prices suggested that the carrying value of a group of merchant wind assets, located in West Texas, may be impaired. Upon review, the estimated undiscounted future cash flows and fair value of the group were less than its carrying value. The fair value analysis was based on the income approach using significant unobservable inputs (Level 3) including revenue and generation forecasts, projected capital and maintenance expenditures and discount rates. As a result, long-lived merchant wind assets held and used with a net carrying amount of $41 million were fully impaired and a pre-tax impairment charge of $41 million was recorded during 2018 within Operating and maintenance expense in Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. During the first quarter of 2018, Mystic Unit 9 did not clear in the ISO-NE capacity auction for the 2021 - 2022 planning year. On March 29, 2018, Generation notified ISO-NE of the early retirement of its Mystic Generating Station's Units 7, 8, 9 and the Mystic Jet Unit (Mystic Generating Station assets) absent regulatory reforms. These events suggested that the carrying value of its New England asset group may be impaired. As a result, Generation completed a comprehensive review of the estimated undiscounted future cash flows of the New England asset group and no impairment charge was required. Further developments such as the failure of ISO-NE to adopt long-term solutions for reliability and fuel security could potentially result in future impairments of the New England asset group, which could be material. See Note 8 — Early Plant Retirements for additional information. In the third quarter of 2015, PHI entered into a sponsorship agreement with the District of Columbia for future sponsorship rights associated with public property within the District of Columbia and paid the District of Columbia $25 million , which Exelon and PHI had recorded as a finite-lived intangible asset as of December 31, 2016. The specific sponsorship rights were to be determined over time through future negotiations. In the fourth quarter of 2017, based upon the lack of currently available sponsorship opportunities, the asset was written off and a pre-tax impairment charge of $25 million was recorded within Operating and maintenance expense in Exelon’s and PHI’s Consolidated Statements of Operations and Comprehensive Income. On May 2, 2017, EGTP entered into a consent agreement with its lenders to initiate an orderly sales process to sell the assets of its wholly owned subsidiaries. As a result, Exelon and Generation classified certain of EGTP's assets and liabilities as held for sale at their respective fair values less costs to sell and recorded a pre-tax impairment charge of $460 million within Operating and maintenance expense in their Consolidated Statements of Operations and Comprehensive Income during 2017. On November 7, 2017, EGTP and its wholly owned subsidiaries filed voluntary petitions for relief under Chapter 11 of Title 11 of the United States Code in the United States Bankruptcy Court for the District of Delaware and, as a result, Exelon and Generation deconsolidated EGTP's assets and liabilities from their consolidated financial statements. See Note 5 — Mergers, Acquisitions and Dispositions for additional information. In the second quarter of 2016, updates to Exelon's long-term view of energy and capacity prices suggested that the carrying value of a group of merchant wind assets, located in West Texas, may be impaired. Upon review, the estimated undiscounted future cash flows and fair value of the group were less than their carrying value. The fair value analysis was based on the income approach using significant unobservable inputs (Level 3) including revenue and generation forecasts, projected capital and maintenance expenditures and discount rates. As a result of the fair value analysis, long-lived merchant wind assets held and used with a carrying amount of approximately $60 million were written down to their fair value of $24 million and a pre-tax impairment charge of $36 million was recorded during the second quarter of 2016 in Operating and maintenance expense in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. In the first quarter of 2016, significant changes in Generation’s intended use of the Upstream oil and gas assets, developments with nonrecourse debt held by its Upstream subsidiary CEU Holdings, LLC (as described in Note 13 — Debt and Credit Agreements ) and continued declines in both production volumes and commodity prices suggested that the carrying value may be impaired. Generation concluded that the estimated undiscounted future cash flows and fair value of its Upstream properties were less than their carrying values. As a result, a pre-tax impairment charge of $119 million was recorded in March 2016 within Operating and maintenance expense in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. On June 16, 2016, Generation initiated the sales process of its Upstream natural gas and oil exploration and production business by executing a forbearance agreement with the lenders of the nonrecourse debt, see Note 13 — Debt and Credit Agreements for additional information. An additional pre-tax impairment charge of $15 million was recorded in September 2016 within Operating and maintenance expense in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income due to further declines in fair value. In December 2016, Generation sold substantially all of the Upstream Assets. See Note 5 — Mergers, Acquisitions and Dispositions for additional information. The fair value analysis used in the above impairments was primarily based on the income approach using significant unobservable inputs (Level 3) including revenue, generation and production forecasts, projected capital and maintenance expenditures and discount rates. Changes in the assumptions described above could potentially result in future impairments of Exelon’s long-lived assets, which could be material. Like-Kind Exchange Transaction (Exelon) In June 2000, UII, LLC (formerly Unicom Investments, Inc.) (UII), a wholly owned subsidiary of Exelon Corporation, entered into transactions pursuant to which UII invested in coal-fired generating station leases (Headleases) with the Municipal Electric Authority of Georgia (MEAG). The generating stations were leased back to MEAG as part of the transactions (Leases). Pursuant to the applicable authoritative guidance, Exelon is required to review the estimated residual values of its direct financing lease investments at least annually and record an impairment charge if the review indicates an other-than-temporary decline in the fair value of the residual values below their carrying values. Exelon estimates the fair value of the residual values of its direct financing lease investments based on the income approach, which uses a discounted cash flow analysis, taking into consideration significant unobservable inputs (Level 3) including the expected revenues to be generated and costs to be incurred to operate the plants over their remaining useful lives subsequent to the lease end dates. Significant assumptions used in estimating the fair value include fundamental energy and capacity prices, fixed and variable costs, capital expenditure requirements, discount rates, tax rates and the estimated remaining useful lives of the plants. The estimated fair values also reflect the cash flows associated with the service contract option discussed above given that a market participant would take into consideration all of the terms and conditions contained in the lease agreements. All the Headleases were terminated by the second quarter of 2016, and no events occurred prior to the termination that required Exelon to review the estimated residual values of the direct financing lease investments in 2016. On March 31, 2016, UII and MEAG finalized an agreement to terminate the MEAG Headleases, the MEAG Leases, and other related agreements prior to their expiration dates. As a result of the lease termination, UII received an early termination payment of $360 million from MEAG and wrote-off the $356 million net investment in the MEAG Headleases and the Leases. The transaction resulted in a pre-tax gain of $4 million which is reflected in Operating and maintenance expense in Exelon's Consolidated Statements of Operations and Comprehensive Income. See Note 14 — Income Taxes for additional information. |
Early Plant Retirements Early P
Early Plant Retirements Early Plant Retirements (Exelon, Generation) | 12 Months Ended |
Dec. 31, 2018 | |
Implications of Potential Early Plant Retirements [Abstract] | |
Implications Of Potential Early Retirement Disclosure [Text Block] | Early Plant Retirements (Exelon and Generation) Exelon and Generation continuously evaluate factors that affect the current and expected economic value of Generation’s plants, including, but not limited to: market power prices, results of capacity auctions, potential legislative and regulatory solutions to ensure plants are fairly compensated for the benefits they provide through their carbon-free emissions, reliability, or fuel security, and the impact of potential rules from the EPA requiring reduction of carbon and other emissions and the efforts of states to implement those final rules. The precise timing of an early retirement date for any plant, and the resulting financial statement impacts, may be affected by many factors, including the status of potential regulatory or legislative solutions, results of any transmission system reliability study assessments, the nature of any co-owner requirements and stipulations, and NDT fund requirements for nuclear plants, among other factors. However, the earliest retirement date for any plant would usually be the first year in which the unit does not have capacity or other obligations, and where applicable, just prior to its next scheduled nuclear refueling outage. Nuclear Generation In 2015 and 2016, Generation identified the Clinton and Quad Cities nuclear plants in Illinois, Ginna and Nine Mile Point nuclear plants in New York and Three Mile Island nuclear plant in Pennsylvania as having the greatest risk of early retirement based on economic valuation and other factors. On June 2, 2016, Generation announced it would shutdown the Clinton and Quad Cities nuclear plants on June 1, 2017 and June 1, 2018, respectively, given a lack of progress on Illinois energy legislation and MISO market reforms, and capacity auctions results that failed to cover cash operating costs and a risk-adjusted rate of return to shareholders. On December 7, 2016, Illinois FEJA was signed into law by the Governor of Illinois and included a ZES that now provides compensation to Clinton and Quad Cities for the carbon-free attributes of their production through 2027. With the passage of the Illinois ZES in December 2016, Generation reversed its June 2016 decision to permanently cease generation operations at the Clinton and Quad Cities nuclear generating plants. Clinton and Quad Cities are currently licensed to operate through 2026 and 2032, respectively. See Note 4 - Regulatory Matters for additional information on the Illinois FEJA and the ZES. In New York, the Ginna and Nine Mile Point nuclear plants faced similar economic challenges and on August 1, 2016, the NYPSC issued an order adopting the CES, which now provides payments to Ginna and Nine Mile Point, as well as FitzPatrick, for the environmental attributes of their production through 2029. Ginna and Nine Mile Point Unit 1 are currently licensed to operate through 2029, and Nine Mile Point Unit 2 through 2046. See Note 4 - Regulatory Matters for additional information on the New York CES. Assuming the continued effectiveness of both the Illinois ZES and the New York CES, Generation and CENG, through its ownership of Ginna and Nine Mile Point, no longer consider Clinton, Quad Cities, Ginna or Nine Mile Point to be at heightened risk for early retirement. However, to the extent either the Illinois ZES or the New York CES programs do not operate as expected over their full terms, each of these plants could again be at heightened risk for early retirement, which could have a material impact on Exelon’s and Generation’s future financial statements. In Pennsylvania, the TMI nuclear plant failed to clear in the May 2017 PJM capacity auction for the 2020-2021 planning year, the third consecutive year that TMI failed to clear in the PJM base residual capacity auction and on May 30, 2017, based on these capacity auction results, prolonged periods of low wholesale power prices, and the absence of federal or state policies that place a value on nuclear energy for its ability to produce electricity without air pollution, Exelon announced that Generation will permanently cease generation operations at TMI on or about September 30, 2019. TMI is currently committed to operate through May 2019 and is licensed to operate through 2034. Generation has filed the required market and regulatory notifications to shutdown the plant. PJM has subsequently notified Generation that it has not identified any reliability issues and has approved the deactivation of TMI as proposed. In 2010, Generation announced that Oyster Creek would retire by the end of 2019 as part of an agreement with the State of New Jersey to avoid significant costs associated with the construction of cooling towers to meet the State's then new environmental regulations. Since then, like other nuclear sites, Oyster Creek continued to face rising operating costs amid a historically low wholesale power price environment. On February 2, 2018, Exelon announced that Generation will permanently cease generation operations at the Oyster Creek nuclear plant at the end of its current operating cycle and permanently ceased generation operations in September 2018. As a result of these early nuclear plant retirement decisions, Exelon and Generation recognized one-time charges in Operating and maintenance expense related to materials and supplies inventory reserve adjustments, employee-related costs and CWIP impairments, among other items. In addition to these one-time charges, annual incremental non-cash charges to earnings stemming from shortening the expected economic useful lives primarily related to accelerated depreciation of plant assets (including any ARC), accelerated amortization of nuclear fuel, and additional ARO accretion expense associated with the changes in decommissioning timing and cost assumptions were also recorded. See Note 15 — Asset Retirement Obligations for additional information on changes to the nuclear decommissioning ARO balance. The total annual impact of these charges by year are summarized in the table below. Income statement expense (pre-tax) 2018 (a) 2017 (b) 2016 (c) Depreciation and Amortization Accelerated depreciation (d) $ 539 $ 250 $ 712 Accelerated nuclear fuel amortization 57 12 60 Operating and Maintenance One-time charges (e,f) 32 77 26 Change in ARO accretion, net of any contractual offset (g) — — 2 Contractual offset for ARC depreciation (g) — — (86 ) Total $ 628 $ 339 $ 714 _________ (a) Reflects incremental accelerated depreciation for TMI and Oyster Creek. The Oyster Creek year-to-date amounts are from February 2, 2018 through September 17, 2018. (b) Reflects incremental charges for TMI including incremental accelerated depreciation and amortization from May 30, 2017 through December 31, 2017. (c) Reflects incremental charges for Clinton and Quad Cities including incremental accelerated depreciation and amortization from June 2, 2016 through December 6, 2016. In December 2016, as a result of reversing its retirement decision for Clinton and Quad Cities, Exelon and Generation updated the expected economic useful life for both facilities, to 2027 for Clinton, commensurate with the end of the Illinois ZES, and to 2032 for Quad Cities, the end of its current operating license. Depreciation was therefore adjusted beginning December 7, 2016, to reflect these extended useful life estimates. (d) Reflects incremental accelerated depreciation of plant assets, including any ARC. (e) Primarily includes materials and supplies inventory reserve adjustments, employee related costs and CWIP impairments. Excludes the charge to Operating and maintenance expense from the ARO remeasurement due to the announced sale of Oyster Creek. See Note 5 — Mergers, Acquisitions and Dispositions for additional information. (f) In June 2016, as a result of the retirement decision for Clinton and Quad Cities, Exelon and Generation recognized one-time charges of $146 million . In December 2016, as a result of reversing its retirement decision for Clinton and Quad Cities, Exelon and Generation reversed approximately $120 million of these one-time charges initially recorded in June 2016. (g) For Quad Cities based on the regulatory agreement with the ICC, decommissioning-related activities are offset within Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. The offset results in an equal adjustment to the noncurrent payables to ComEd at Generation and an adjustment to the regulatory liabilities at ComEd. Likewise, ComEd has recorded an equal noncurrent affiliate receivable from Generation and corresponding regulatory liability. In 2017, PSEG made public similar financial challenges facing its New Jersey nuclear plants, including Salem, of which Generation owns a 42.59% ownership interest. PSEG is the operator of Salem and also has the decision making authority to retire Salem. On May 23, 2018, New Jersey enacted legislation that established a ZEC program, similar to that in Illinois and New York, that will provide compensation for nuclear plants that demonstrate to the NJBPU that they meet certain requirements, including that they make a significant contribution to air quality in the state and that their revenues are insufficient to cover their costs and risks. The NJBPU must complete its processes for determining eligibility for, and participation in, the ZEC program by April 18, 2019. On December 19, 2018, PSEG submitted its application for Salem. Assuming the successful implementation of the New Jersey ZEC program and the selection of Salem as one of the qualifying facilities, the New Jersey ZEC program has the potential to mitigate the heightened risk of earlier retirement for Salem. See Note 4 - Regulatory Matters for additional information. The following table provides the balance sheet amounts as of December 31, 2018 for Generation’s ownership share of the significant assets and liabilities associated with Salem that would potentially be impacted by a decision to permanently cease generation operations. December 31, 2018 Asset Balances Materials and supplies inventory $ 45 Nuclear fuel inventory, net 118 Completed plant, net 538 Construction work in progress 44 Liability Balances Asset retirement obligation (395 ) NRC License Renewal Term 2036 (unit 1) 2040 (unit 2) Generation’s Dresden, Byron, and Braidwood nuclear plants in Illinois are also showing increased signs of economic distress, which could lead to an early retirement, in a market that does not currently compensate them for their unique contribution to grid resiliency and their ability to produce large amounts of energy without carbon and air pollution. The May 2018 PJM capacity auction for the 2021-2022 planning year resulted in the largest volume of nuclear capacity ever not selected in the auction, including all of Dresden, and portions of Byron and Braidwood. Exelon continues to work with stakeholders on state policy solutions, while also advocating for broader market reforms at the regional and federal level. Other Generation On March 29, 2018, Generation notified grid operator ISO-NE of its plans to early retire its Mystic Generating Station assets absent regulatory reforms on June 1, 2022, at the end of the current capacity commitment for Mystic Units 7 and 8. Mystic Unit 9 is currently committed through May 2021. The ISO-NE announced that it would take a three-step approach to fuel security. • First, on May 1, 2018, ISO-NE made a filing with FERC requesting waiver of certain tariff provisions to allow it to retain Mystic Units 8 and 9 for fuel security for the 2022 - 2024 capacity commitment periods. FERC denied the waiver request on procedural grounds on July 2, 2018 and ordered ISO-NE to (i) make a filing within 60 days providing for the filing of a short-term cost-of-service agreement to address fuel security concerns and (ii) make a filing by July 1, 2019 proposing permanent tariff revisions that would improve its market design to better address regional fuel security concerns. • Second, in accordance with FERC's July 2, 2018 order, on August 31, 2018, ISO-NE made a filing with FERC proposing short-term tariff changes to permit it to retain a resource for fuel security reliability reasons, which FERC accepted on December 3, 2018. • Third, ISO-NE stated its intention to work with stakeholders to develop long-term market rule changes to address system resiliency considering significant reliability risks identified in ISO-NE’s January 2018 fuel security report. Changes to market rules are necessary because critical units to the region, such as Mystic Units 8 and 9, cannot recover future operating costs, including the cost of procuring fuel. In its July 2, 2018 order, FERC ordered ISO-NE to make a filing by July 1, 2019 proposing permanent tariff revisions that would improve its market design to better address regional fuel security concerns. In January 2019, ISO-NE has indicated that it intends to seek an extension of the deadline for this filing to November 15, 2019. On May 16, 2018, Generation made a filing with FERC to establish cost-of-service compensation and terms and conditions of service for Mystic Units 8 and 9 for the period between June 1, 2022 - May 31, 2024. Among the costs included in the filing are costs associated with the Everett Marine Terminal. On December 20, 2018, FERC issued an order accepting the cost of service agreement reflecting a number of adjustments to the annual fixed revenue requirement and allowing for recovery of a substantial portion of the costs associated with the Everett Marine Terminal. FERC also directed a paper hearing on ROE using a new methodology. Initial and reply briefs on ROE will be due on April 18, 2019 and July 18, 2019. These will be reflected in a compliance filing due February 18, 2019. On January 4, 2019, Generation notified ISO-NE that it will participate in the Forward Capacity Market auction for the 2022 - 2023 capacity commitment period. In addition, on January 22, 2019, Exelon and several other parties filed requests for rehearing of certain findings of the December 20, 2018 order. The request for rehearing does not alter Generation's commitment to participate in the Forward Capacity Auction for the 2022-2023 capacity commitment period. The following table provides the balance sheet amounts as of December 31, 2018 for Generation’s significant assets and liabilities associated with the Mystic Units 8 and 9 and Everett Marine Terminal assets that would potentially be impacted by a decision to permanently cease generation operations. December 31, 2018 Asset Balances Materials and supplies inventory $ 30 Fuel inventory 20 Completed plant, net 901 Construction work in progress 9 Liability Balances Asset retirement obligation (1 ) To ensure the continued reliable supply of fuel to Mystic Units 8 and 9 while they remain operating, on October 1, 2018, Generation acquired the Everett Marine Terminal in Massachusetts for a purchase price of $81 million , with the majority of the fair value allocated to Property, plant and equipment and no goodwill recorded. Generation also settled its existing long-term gas supply agreement, resulting in a pre-tax gain of $75 million , which is included within Purchased power and fuel expense in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. |
Jointly Owned Electric Utility
Jointly Owned Electric Utility Plant (Exelon, Generation, PECO, BGE, PHI, Pepco, DPL and ACE) | 12 Months Ended |
Dec. 31, 2018 | |
Public Utilities, Property, Plant and Equipment [Abstract] | |
Jointly Owned Electric Utility Plant | Jointly Owned Electric Utility Plant (Exelon, Generation, PECO, BGE, PHI, Pepco, DPL and ACE) Exelon's, Generation's, PECO's, BGE's, Pepco's, DPL's and ACE's undivided ownership interests in jointly owned electric plants and transmission facilities at December 31, 2018 and 2017 were as follows: Nuclear Generation Fossil-Fuel Generation Transmission Other Quad Cities Peach Bottom Salem (a) Nine Mile Point Unit 2 Wyman PA (b) NJ/ DE (c) Other (d) Operator Generation Generation PSEG Generation FP&L First PSEG/ DPL various Ownership interest 75.00 % 50.00 % 42.59 % 82.00 % 5.89 % various various various Exelon’s share at December 31, 2018: Plant (e) $ 1,131 $ 1,451 $ 648 $ 910 $ 4 $ 28 $ 103 $ 15 Accumulated depreciation (e) 587 523 227 126 3 16 53 13 Construction work in progress 13 15 44 56 — 1 — — Exelon’s share at December 31, 2017: Plant (e) $ 1,074 $ 1,417 $ 631 $ 839 $ 3 $ 27 $ 102 $ 15 Accumulated depreciation (e) 550 461 205 97 3 15 52 13 Construction work in progress 35 18 33 55 — — — — __________ (a) Generation also owns a proportionate share in the fossil-fuel combustion turbine at Salem, which is fully depreciated. The gross book value was $3 million at December 31, 2018 and 2017 . (b) PECO, BGE, Pepco, DPL and ACE own a 22% , 7% , 27% , 9% and 8% share, respectively, in 127 miles of 500 kV lines located in Pennsylvania as well as a 20.72% , 10.56% , 9.72% , 3.72% and 3.83% share, respectively, of a 500 kV substation immediately outside of the Conemaugh fossil-generating station which supplies power to the 500 kV lines including, but not limited to, the lines noted above. (c) PECO, DPL and ACE own a 42.55% , 1% and 13.9% share, respectively in 151.3 miles of 500 kV lines located in New Jersey and of the Salem generating plant substation. PECO, DPL and ACE also own a 42.55% , 7.45% and 7.45% share, respectively, in 2.5 miles of 500 kV line located over the Delaware River. ACE also has a 21.78% share in a 500 kV New Freedom Switching substation. (d) Generation, DPL and ACE own a 44.24% , 11.91% and 4.83% share, respectively in assets located at Merrill Creek Reservoir located in New Jersey. Pepco, DPL and ACE own a 11.9% , 7.4% and 6.6% share, respectively, in Valley Forge Corporate Center. (e) Excludes asset retirement costs and general plant. Exelon’s, Generation’s, PECO's, BGE's, Pepco's, DPL's and ACE's undivided ownership interests are financed with their funds and all operations are accounted for as if such participating interests were wholly owned facilities. Exelon’s, Generation’s, PECO's, BGE's, Pepco's, DPL's and ACE's share of direct expenses of the jointly owned plants are included in Purchased power and fuel and Operating and maintenance expenses in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income and in Operating and maintenance expenses in PECO's, BGE's, Pepco's, DPL's and ACE's Consolidated Statements of Operations and Comprehensive Income. |
Intangible Assets (All Registra
Intangible Assets (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Goodwill and Intangible Assets Disclosure [Abstract] | |
Intangible Assets (All Registrants) | Intangible Assets (Exelon, Generation, ComEd, PECO, PHI, Pepco, DPL and ACE) Goodwill Exelon’s, ComEd’s and PHI's gross amount of goodwill, accumulated impairment losses and carrying amount of goodwill for the years ended December 31, 2018 and 2017 were as follows: Balance at January 1, 2017 Impairment losses Balance at December 31, 2017 Impairment losses Balance at December 31, 2018 Exelon Gross amount $ 8,660 $ — $ 8,660 $ — $ 8,660 Accumulated impairment loss 1,983 — 1,983 — 1,983 Carrying amount 6,677 — 6,677 — 6,677 ComEd (a) Gross amount 4,608 — 4,608 — 4,608 Accumulated impairment loss 1,983 — 1,983 — 1,983 Carrying amount 2,625 — 2,625 — 2,625 PHI (b) Gross amount 4,005 — 4,005 — 4,005 Carrying amount 4,005 — 4,005 — 4,005 __________ (a) Reflects goodwill recorded in 2000 from the PECO/Unicom merger (predecessor parent company of ComEd). (b) Reflects goodwill recorded in 2016 from the PHI merger. Goodwill is not amortized, but is subject to an assessment for impairment at least annually, or more frequently if events occur or circumstances change that would more likely than not reduce the fair value of ComEd's and PHI's reporting units below their carrying amounts. A reporting unit is an operating segment or one level below an operating segment (known as a component) and is the level at which goodwill is tested for impairment. A component of an operating segment is a reporting unit if the component constitutes a business for which discrete financial information is available and its operating results are regularly reviewed by segment management. ComEd has a single operating segment. PHI's operating segments are Pepco, DPL and ACE. See Note 24 — Segment Information for additional information. There is no level below these operating segments for which operating results are regularly reviewed by segment management. Therefore, the ComEd, Pepco, DPL and ACE operating segments are also considered reporting units for goodwill impairment testing purposes. Exelon's and ComEd's $2.6 billion of goodwill has been assigned entirely to the ComEd reporting unit. PHI identified an error related to the allocation of goodwill to its reporting units in 2016 while performing the 2018 annual impairment assessment. As revised in 2018, Exelon's and PHI's $4 billion of goodwill has been assigned to the Pepco, DPL and ACE reporting units in the amounts of $2.1 billion , $1.4 billion and $0.5 billion , respectively, an increase (decrease) of $0.4 billion , $0.3 billion , and $(0.7) billion for Pepco, DPL and ACE, respectively, from the originally reported amounts. This error did not result in a change to the total amount of goodwill recorded at PHI nor would it have resulted in an impairment of PHI's goodwill in 2016 or 2017. Therefore, management has concluded that the error is not material to the previously issued financial statements. Entities assessing goodwill for impairment have the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. In performing a qualitative assessment, entities should assess, among other things, macroeconomic conditions, industry and market considerations, overall financial performance, cost factors and entity-specific events. If an entity determines, on the basis of qualitative factors, that the fair value of the reporting unit is more likely than not greater than the carrying amount, no further testing is required. If an entity bypasses the qualitative assessment or performs the qualitative assessment but determines that it is more likely than not that its fair value is less than its carrying amount, a quantitative two-step, fair value-based test is performed. Exelon's, ComEd's and PHI's accounting policy is to perform a quantitative test of goodwill at least once every three years. The first step in the quantitative test compares the fair value of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, the second step is performed. The second step requires an allocation of fair value to the individual assets and liabilities using purchase price allocation authoritative guidance in order to determine the implied fair value of goodwill. If the implied fair value of goodwill is less than the carrying amount, an impairment loss is recorded as a reduction to goodwill and a charge to operating expense. Application of the goodwill impairment test requires management judgment, including the identification of reporting units and determining the fair value of the reporting unit, which management estimates using a weighted combination of a discounted cash flow analysis and a market multiples analysis. Significant assumptions used in these fair value analyses include discount and growth rates, utility sector market performance and transactions, projected operating and capital cash flows for ComEd's, Pepco's, DPL's and ACE's businesses and the fair value of debt. In applying the second step (if needed), management must estimate the fair value of specific assets and liabilities of the reporting unit. 2018 and 2017 Goodwill Impairment Assessment. ComEd and PHI qualitatively determined that it was more likely than not that the fair values of their reporting units exceeded their carrying values and, therefore, did not perform quantitative assessments as of November 1, 2018 and 2017 for ComEd and as of November 1, 2017 for PHI. As part of their qualitative assessments, ComEd and PHI evaluated, among other things, management’s best estimate of projected operating and capital cash flows for their businesses, outcomes of recent regulatory proceedings, changes in certain market conditions, including the discount rate and regulated utility peer company EBITDA multiples, while also considering, the passing margin from their last quantitative assessments as of November 1, 2016. As a result of the reallocation of goodwill to PHI’s reporting units as discussed above, as of November 1, 2018, PHI performed a quantitative test for its 2018 annual goodwill impairment assessment. The first step of the test comparing the estimated fair values of the Pepco, DPL and ACE reporting units to their carrying values, including goodwill, indicated no impairments of goodwill; therefore, no second step was required. While the annual assessments indicated no impairments, certain assumptions used to estimate reporting unit fair values are highly sensitive to changes. Adverse regulatory actions or changes in significant assumptions could potentially result in future impairments of Exelon's, ComEd's and PHI’s goodwill, which could be material. Based on the results of the annual goodwill test performed as of November 1, 2016 and November 1, 2018 for ComEd and PHI, respectively, the estimated fair values of the ComEd, Pepco, DPL and ACE reporting units would have needed to decrease by more than 30% , 30% , 20% and 30% , respectively, for ComEd and PHI to fail the first step of their respective impairment tests. Other Intangible Assets and Liabilities Exelon’s, Generation’s, ComEd’s and PHI's other intangible assets and liabilities, included in Unamortized energy contract assets and liabilities and Other deferred debits and other assets in their Consolidated Balance Sheets, consisted of the following as of December 31, 2018 and 2017 : December 31, 2018 December 31, 2017 Gross Accumulated Amortization Net Gross Accumulated Amortization Net Generation Unamortized Energy Contracts (b) 1,957 (1,588 ) 369 1,938 (1,574 ) 364 Customer Relationships 325 (162 ) 163 305 (133 ) 172 Trade Name 243 (171 ) 72 243 (148 ) 95 ComEd Chicago Settlement Agreements (c) 162 (148 ) 14 162 (141 ) 21 PHI Unamortized Energy Contracts (b) (1,515 ) 954 (561 ) (1,515 ) 766 (749 ) Exelon Corporate Software License (a) 95 (34 ) 61 95 (25 ) 70 Exelon $ 1,267 $ (1,149 ) $ 118 $ 1,228 $ (1,255 ) $ (27 ) __________ (a) On May 31, 2015, Exelon entered into a long-term software license agreement. Exelon is required to make payments starting August 2015 through May 2024. The intangible asset recognized as a result of these payments is being amortized on a straight-line basis over the contract term. (b) Includes unamortized energy contract assets and liabilities in Exelon's, Generations and PHI's Consolidated Balance Sheets. (c) In March 1999 and February 2003, ComEd entered into separate agreements with the City of Chicago and Midwest Generation, LLC. Under the terms of the settlement, ComEd agreed to make payments to the City of Chicago. The intangible asset recognized as a result of the settlement agreement is being amortized ratably over the remaining term of the City of Chicago franchise agreement. The following table summarizes the estimated future amortization expense related to intangible assets and liabilities as of December 31, 2018 : For the Years Ending December 31, Exelon Generation ComEd PHI 2019 $ (32 ) $ 70 $ 7 $ (119 ) 2020 (20 ) 78 7 (115 ) 2021 (4 ) 78 — (92 ) 2022 (23 ) 56 — (89 ) 2023 (21 ) 50 — (81 ) The following table summarizes the amortization expense related to intangible assets and liabilities for each of the years ended December 31, 2018 , 2017 and 2016 : For the Years Ended December 31, Exelon (a)(b) Generation (a) ComEd PHI (b) 2018 $ (109 ) $ 63 $ 7 $ (188 ) 2017 (237 ) 83 7 (336 ) 2016 (336 ) 79 7 (430 ) __________ (a) At Exelon and Generation, amortization of unamortized energy contracts totaling $14 million , $35 million and $35 million for the years ended December 31, 2018 , 2017 and 2016 , respectively, was recorded in Operating revenues or Purchased power and fuel expense in their Consolidated Statements of Operations and Comprehensive Income. (b) At Exelon and PHI, amortization of the unamortized energy contract fair value adjustment amounts and the corresponding offsetting regulatory asset and liability amounts are amortized through Purchased power and fuel expense in their Consolidated Statements of Operations and Comprehensive Income. Acquired Intangible Assets and Liabilities Business combinations require the acquirer to separately recognize identifiable intangible assets in the application of purchase accounting. Unamortized Energy Contracts. Unamortized energy contract assets and liabilities represent the remaining unamortized fair value of non-derivative energy contracts that Exelon and Generation have acquired. The valuation of unamortized energy contracts was estimated by applying either the market approach or the income approach depending on the nature of the underlying contract. The market approach was utilized when prices and other relevant information generated by market transactions involving comparable transactions were available. Otherwise, the income approach, which is based upon discounted projected future cash flows associated with the underlying contracts, was utilized. The fair value is based upon certain unobservable inputs, which are considered Level 3 inputs, pursuant to applicable authoritative guidance. Key estimates and inputs include forecasted power and fuel prices and the discount rate. The Exelon Wind unamortized energy contracts are amortized on a straight-line basis over the period in which the associated contract revenues are recognized as a decrease in Operating revenues within Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. In the case of Antelope Valley, Constellation, CENG, Integrys and ConEdison, the fair value amounts are amortized over the life of the contract in relation to the present value of the underlying cash flows as of the acquisition dates through either Operating revenues or Purchased power and fuel expense within Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. At PHI, offsetting regulatory assets or liabilities were also recorded. The unamortized energy contract assets and liabilities and any corresponding regulatory assets or liabilities, respectively, are amortized over the life of the contract in relation to the expected realization of the underlying cash flows. Customer Relationships. The customer relationship intangibles were determined based on a “multi-period excess method” of the income approach. Under this method, the intangible asset’s fair value is determined to be the estimated future cash flows that will be earned on the current customer base, taking into account expected contract renewals based on customer attrition rates and costs to retain those customers. The fair value is based upon certain unobservable inputs, which are considered Level 3 inputs, pursuant to applicable authoritative guidance. Key assumptions include the customer attrition rate and the discount rate. The authoritative guidance requires that customer-based intangibles be amortized over the period expected to be benefited using the pattern of economic benefit. The amortization of the customer relationships recorded in Depreciation and amortization expense within Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. Trade Name. The Constellation trade name intangible was determined based on the relief from royalty method of income approach whereby fair value is determined to be the present value of the license fees avoided by owning the assets. The fair value is based upon certain unobservable inputs, which are considered Level 3 inputs, pursuant to applicable authoritative guidance. Key assumptions include the hypothetical royalty rate and the discount rate. The Constellation trade name intangible is amortized on a straight-line basis over a period of 10 years . The amortization of the trade name is recorded in Depreciation and amortization expense within Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. Renewable Energy Credits and Alternative Energy Credits (Exelon, Generation, PECO, PHI, DPL and ACE) Exelon’s, Generation’s, PECO's, PHI's, DPL's and ACE's other intangible assets, included in Other current assets and Other deferred debits and other assets in the Consolidated Balance Sheets, include RECs (Exelon, Generation, PHI, DPL and ACE) and AECs (Exelon and PECO). Purchased RECs are recorded at cost on the date they are purchased. The cost of RECs purchased on a stand-alone basis is based on the transaction price, while the cost of RECs acquired through PPAs represents the difference between the total contract price and the market price of energy at contract inception. Generally, revenue for RECs that are sold to a counterparty under a contract that specifically identifies a power plant is recognized at a point in time when the power is produced. This includes both bundled and unbundled REC sales. Otherwise, the revenue is recognized upon physical transfer of the REC to the customer. The following table summarizes the current and noncurrent Renewable and Alternative Energy Credits as of December 31, 2018 and 2017 : As of December 31, 2018 Exelon Generation PECO PHI DPL ACE Current AEC's $ 2 $ — $ 2 $ — $ — $ — Current REC's 279 270 — 9 8 1 Noncurrent REC's 52 52 — — — — As of December 31, 2017 Exelon Generation PECO PHI DPL ACE Current AEC's $ 1 $ — $ 1 $ — $ — $ — Current REC's 321 312 — 9 8 1 Noncurrent REC's 27 27 — — — — |
Fair Value of Financial Assets
Fair Value of Financial Assets and Liabilities (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Fair Value Disclosures [Abstract] | |
Fair Value of Financial Assets and Liabilities (All Registrants) | Fair Value of Financial Assets and Liabilities (All Registrants) Fair Value of Financial Liabilities Recorded at the Carrying Amount The following tables present the carrying amounts and fair values of the Registrants’ short-term liabilities, long-term debt, SNF obligation, and trust preferred securities (long-term debt to financing trusts or junior subordinated debentures) as of December 31, 2018 and 2017 : Exelon December 31, 2018 Carrying Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 714 $ — $ 714 $ — $ 714 Long-term debt (including amounts due within one year) (a) 35,424 — 33,711 2,158 35,869 Long-term debt to financing trusts (b) 390 — — 400 400 SNF obligation 1,171 — 949 — 949 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 929 $ — $ 929 $ — $ 929 Long-term debt (including amounts due within one year) (a) 34,264 — 34,735 1,970 36,705 Long-term debt to financing trusts (b) 389 — — 431 431 SNF obligation 1,147 — 936 — 936 Generation December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 8,793 $ — $ 7,467 $ 1,443 $ 8,910 SNF obligation 1,171 — 949 — 949 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 2 $ — $ 2 $ — $ 2 Long-term debt (including amounts due within one year) (a) 8,990 — 7,839 1,673 9,512 SNF obligation 1,147 — 936 — 936 ComEd December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 8,101 $ — $ 8,390 $ — $ 8,390 Long-term debt to financing trusts (b) 205 — — 209 209 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 7,601 $ — $ 8,418 $ — $ 8,418 Long-term debt to financing trusts (b) 205 — — 227 227 PECO December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 3,084 $ — $ 3,157 $ 50 $ 3,207 Long-term debt to financing trusts 184 — — 191 191 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 2,903 $ — $ 3,194 $ — $ 3,194 Long-term debt to financing trusts 184 — — 204 204 BGE December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 35 $ — $ 35 $ — $ 35 Long-term debt (including amounts due within one year) (a) 2,876 — 2,950 — 2,950 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 77 $ — $ 77 $ — $ 77 Long-term debt (including amounts due within one year) (a) 2,577 — 2,825 — 2,825 PHI December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 179 $ — $ 179 $ — $ 179 Long-term debt (including amounts due within one year) (a) 6,259 — 5,436 665 6,101 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 350 $ — $ 350 $ — $ 350 Long-term debt (including amounts due within one year) (a) 5,874 — 5,722 297 6,019 Pepco December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 40 $ — $ 40 $ — $ 40 Long-term debt (including amounts due within one year) (a) 2,719 — 2,901 196 3,097 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 26 $ — $ 26 $ — $ 26 Long-term debt (including amounts due within one year) (a) 2,540 — 3,114 9 3,123 DPL December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 1,494 $ — $ 1,303 $ 193 $ 1,496 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 216 $ — $ 216 $ — $ 216 Long-term debt (including amounts due within one year) (a) 1,300 — 1,393 — 1,393 ACE December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 139 $ — $ 139 $ — $ 139 Long-term debt (including amounts due within one year) (a) 1,188 — 987 275 1,262 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 108 $ — $ 108 $ — $ 108 Long-term debt (including amounts due within one year) (a) 1,121 — 949 288 1,237 __________ (a) Includes unamortized debt issuance costs which are not fair valued of $216 million , $51 million , $63 million , $23 million , $18 million , $14 million , $34 million , $12 million and $7 million for Exelon, Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE respectively, as of December 31, 2018 . Includes unamortized debt issuance costs which are not fair valued of $201 million , $60 million , $52 million , $17 million , $17 million , $6 million , $32 million , $11 million and $5 million for Exelon, Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE respectively, as of December 31, 2017 . (b) Includes unamortized debt issuance costs which are not fair valued of $0 million and $1 million for Exelon and ComEd, respectively, as of December 31, 2018 . Includes unamortized debt issuance costs which are not fair valued of $1 million and $1 million for Exelon and ComEd, respectively, as of December 31, 2017 . Short-Term Liabilities. The short-term liabilities included in the tables above are comprised of dividends payable (included in Other current liabilities) (Level 1) and short-term borrowings (Level 2). The Registrants’ carrying amounts of the short-term liabilities are representative of fair value because of the short-term nature of these instruments. Long-Term Debt. The fair value amounts of Exelon’s taxable debt securities (Level 2) and private placement taxable debt securities (Level 3) are determined by a valuation model that is based on a conventional discounted cash flow methodology and utilizes assumptions of current market pricing curves. In order to incorporate the credit risk of the Registrants into the discount rates, Exelon obtains pricing (i.e., U.S. Treasury rate plus credit spread) based on trades of existing Exelon debt securities as well as debt securities of other issuers in the utility sector with similar credit ratings in both the primary and secondary market, across the Registrants’ debt maturity spectrum. The credit spreads of various tenors obtained from this information are added to the appropriate benchmark U.S. Treasury rates in order to determine the current market yields for the various tenors. The yields are then converted into discount rates of various tenors that are used for discounting the respective cash flows of the same tenor for each bond or note. Due to low trading volume of private placement debt, qualitative factors such as market conditions, low volume of investors and investor demand, this debt is classified as Level 3. The fair value of Generation’s and Pepco's non-government-backed fixed rate nonrecourse debt (Level 3) is based on market and quoted prices for its own and other nonrecourse debt with similar risk profiles. Given the low trading volume in the nonrecourse debt market, the price quotes used to determine fair value will reflect certain qualitative factors, such as market conditions, investor demand, new developments that might significantly impact the project cash flows or off-taker credit, and other circumstances related to the project (e.g., political and regulatory environment). The fair value of Generation’s government-backed fixed rate project financing debt (Level 3) is largely based on a discounted cash flow methodology that is similar to the taxable debt securities methodology described above. Due to the lack of market trading data on similar debt, the discount rates are derived based on the original loan interest rate spread to the applicable Treasury rate as well as a current market curve derived from government-backed securities. Variable rate financing debt resets on a monthly or quarterly basis and the carrying value approximates fair value (Level 2). When trading data is available on variable rate financing debt, the fair value is based on market and quoted prices for its own and other nonrecourse debt with similar risk profiles (Level 2). Generation, Pepco, DPL and ACE also have tax-exempt debt (Level 2). Due to low trading volume in this market, qualitative factors, such as market conditions, investor demand, and circumstances related to the issuer (e.g., conduit issuer political and regulatory environment), may be incorporated into the credit spreads that are used to obtain the fair value as described above. Variable rate tax-exempt debt (Level 2) resets on a regular basis and the carrying value approximates fair value. SNF Obligation . The carrying amount of Generation’s SNF obligation (Level 2) is derived from a contract with the DOE to provide for disposal of SNF from Generation’s nuclear generating stations. When determining the fair value of the obligation, the future carrying amount of the SNF obligation is calculated by compounding the current book value of the SNF obligation at the 13-week Treasury rate. The compounded obligation amount is discounted back to present value using Generation’s discount rate, which is calculated using the same methodology as described above for the taxable debt securities, and an estimated maturity date of 2030. The carrying amount also includes $119 million and $114 million as of December 31, 2018 and 2017 for the one-time fee obligation associated with closing of the FitzPatrick acquisition on March 31, 2017. The fair value was determined using a similar methodology, however the New York Power Authority's (NYPA) discount rate is used in place of Generation's given the contractual right to reimbursement from NYPA for the obligation; see Note 5 - Mergers, Acquisitions and Dispositions for additional information on Generation's acquisition of FitzPatrick. Long-Term Debt to Financing Trusts . Exelon’s long-term debt to financing trusts is valued based on publicly traded securities issued by the financing trusts. Due to low trading volume of these securities, qualitative factors, such as market conditions, investor demand, and circumstances related to each issue, this debt is classified as Level 3. Recurring Fair Value Measurements Exelon records the fair value of assets and liabilities in accordance with the hierarchy established by the authoritative guidance for fair value measurements. The hierarchy prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows: • Level 1 — quoted prices (unadjusted) in active markets for identical assets or liabilities that the Registrants have the ability to liquidate as of the reporting date. • Level 2 — inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data. • Level 3 — unobservable inputs, such as internally developed pricing models or third-party valuations for the asset or liability due to little or no market activity for the asset or liability. Generation and Exelon In accordance with the applicable guidance on fair value measurement, certain investments that are measured at fair value using the NAV per share as a practical expedient are no longer classified within the fair value hierarchy and are included under "Not subject to leveling" in the table below. The following tables present assets and liabilities measured and recorded at fair value in Exelon's and Generation’s Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of December 31, 2018 and 2017 : Generation Exelon As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Assets Cash equivalents (a) $ 581 $ — $ — $ — $ 581 $ 1,243 $ — $ — $ — $ 1,243 NDT fund investments Cash equivalents (b) 252 86 — — 338 252 86 — — 338 Equities 2,918 1,591 — 1,381 5,890 2,918 1,591 — 1,381 5,890 Fixed income Corporate debt — 1,593 230 — 1,823 — 1,593 230 — 1,823 U.S. Treasury and agencies 2,081 99 — — 2,180 2,081 99 — — 2,180 Foreign governments — 50 — — 50 — 50 — — 50 State and municipal debt — 149 — — 149 — 149 — — 149 Other (c) — 30 — 846 876 — 30 — 846 876 Fixed income subtotal 2,081 1,921 230 846 5,078 2,081 1,921 230 846 5,078 Middle market lending — — 313 367 680 — — 313 367 680 Private equity — — — 329 329 — — — 329 329 Real estate — — — 510 510 — — — 510 510 NDT fund investments subtotal (d) 5,251 3,598 543 3,433 12,825 5,251 3,598 543 3,433 12,825 Generation Exelon As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Pledged assets for Zion Station decommissioning Cash equivalents 9 — — — 9 9 — — — 9 Equities — — — — — — — — — — Middle market lending — — — — — — — — — — Pledged assets for Zion Station decommissioning subtotal 9 — — — 9 9 — — — 9 Rabbi trust investments Cash equivalents 5 — — — 5 48 — — — 48 Mutual funds 24 — — — 24 72 — — — 72 Fixed income — — — — — — 15 — — 15 Life insurance contracts — 22 — — 22 — 70 38 — 108 Rabbi trust investments subtotal (f) 29 22 — — 51 120 85 38 — 243 Commodity derivative assets Economic hedges 541 2,760 1,470 — 4,771 541 2,760 1,470 — 4,771 Proprietary trading — 69 77 — 146 — 69 77 — 146 Effect of netting and allocation of (e) (582 ) (2,357 ) (732 ) — (3,671 ) (582 ) (2,357 ) (732 ) — (3,671 ) Commodity derivative assets subtotal (41 ) 472 815 — 1,246 (41 ) 472 815 — 1,246 Interest rate and foreign currency derivative assets Derivatives designated as hedging instruments — — — — — — — — — — Economic hedges — 13 — — 13 — 13 — — 13 Effect of netting and allocation of collateral — (3 ) — — (3 ) — (3 ) — — (3 ) Interest rate and foreign currency derivative assets subtotal — 10 — — 10 — 10 — — 10 Other investments — — 42 — 42 — — 42 — 42 Total assets 5,829 4,102 1,400 3,433 14,764 6,582 4,165 1,438 3,433 15,618 Generation Exelon As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Liabilities Commodity derivative liabilities Economic hedges (642 ) (2,963 ) (1,027 ) — (4,632 ) (642 ) (2,963 ) (1,276 ) — (4,881 ) Proprietary trading — (73 ) (21 ) — (94 ) — (73 ) (21 ) — (94 ) Effect of netting and allocation of (e) 639 2,581 808 — 4,028 639 2,581 808 — 4,028 Commodity derivative liabilities subtotal (3 ) (455 ) (240 ) — (698 ) (3 ) (455 ) (489 ) — (947 ) Interest rate and foreign currency derivative liabilities Derivatives designated as hedging instruments — — — — — — (4 ) — — (4 ) Economic hedges — (6 ) — — (6 ) — (6 ) — — (6 ) Effect of netting and allocation of collateral — 3 — — 3 — 3 — — 3 Interest rate and foreign currency derivative liabilities subtotal — (3 ) — — (3 ) — (7 ) — — (7 ) Deferred compensation obligation — (35 ) — — (35 ) — (137 ) — — (137 ) Total liabilities (3 ) (493 ) (240 ) — (736 ) (3 ) (599 ) (489 ) — (1,091 ) Total net assets $ 5,826 $ 3,609 $ 1,160 $ 3,433 $ 14,028 $ 6,579 $ 3,566 $ 949 $ 3,433 $ 14,527 Generation Exelon As of December 31, 2017 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Assets Cash equivalents (a) $ 168 $ — $ — $ — $ 168 $ 656 $ — $ — $ — $ 656 NDT fund investments Cash equivalents (b) 135 85 — — 220 135 85 — — 220 Equities 4,163 915 — 2,176 7,254 4,163 915 — 2,176 7,254 Fixed income Corporate debt — 1,614 251 — 1,865 — 1,614 251 — 1,865 U.S. Treasury and agencies 1,917 52 — — 1,969 1,917 52 — — 1,969 Foreign governments — 82 — — 82 — 82 — — 82 State and municipal debt — 263 — — 263 — 263 — — 263 Other (c) — 47 — 510 557 — 47 — 510 557 Fixed income subtotal 1,917 2,058 251 510 4,736 1,917 2,058 251 510 4,736 Generation Exelon As of December 31, 2017 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Middle market lending — — 397 131 528 — — 397 131 528 Private equity — — — 222 222 — — — 222 222 Real estate — — — 471 471 — — — 471 471 NDT fund investments subtotal (d) 6,215 3,058 648 3,510 13,431 6,215 3,058 648 3,510 13,431 Pledged assets for Zion Station decommissioning Cash equivalents 2 — — — 2 2 — — — 2 Equities — 1 — — 1 — 1 — — 1 Middle market lending — — 12 24 36 — — 12 24 36 Pledged assets for Zion Station decommissioning subtotal 2 1 12 24 39 2 1 12 24 39 Rabbi trust investments Cash equivalents 5 — — — 5 77 — — — 77 Mutual funds 23 — — — 23 58 — — — 58 Fixed income — — — — — — 12 — — 12 Life insurance contracts — 22 — — 22 — 71 22 — 93 Rabbi trust investments subtotal (f) 28 22 — — 50 135 83 22 — 240 Commodity derivative assets Economic hedges 557 2,378 1,290 — 4,225 557 2,378 1,290 — 4,225 Proprietary trading 2 31 35 — 68 2 31 35 — 68 Effect of netting and allocation of (e) (585 ) (1,769 ) (635 ) — (2,989 ) (585 ) (1,769 ) (635 ) — (2,989 ) Commodity derivative assets subtotal (26 ) 640 690 — 1,304 (26 ) 640 690 — 1,304 Interest rate and foreign currency derivative assets Derivatives designated as hedging instruments — 3 — — 3 — 6 — — 6 Economic hedges — 10 — — 10 — 10 — — 10 Effect of netting and allocation of collateral (2 ) (5 ) — — (7 ) (2 ) (5 ) — — (7 ) Interest rate and foreign currency derivative assets subtotal (2 ) 8 — — 6 (2 ) 11 — — 9 Other investments — — 37 — 37 — — 37 — 37 Total assets 6,385 3,729 1,387 3,534 15,035 6,980 3,793 1,409 3,534 15,716 Generation Exelon As of December 31, 2017 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Liabilities Commodity derivative liabilities Economic hedges (712 ) (2,226 ) (845 ) — (3,783 ) (713 ) (2,226 ) (1,101 ) — (4,040 ) Proprietary trading (2 ) (42 ) (9 ) — (53 ) (2 ) (42 ) (9 ) — (53 ) Effect of netting and allocation of (e) 650 2,089 716 — 3,455 651 2,089 716 — 3,456 Commodity derivative liabilities subtotal (64 ) (179 ) (138 ) — (381 ) (64 ) (179 ) (394 ) — (637 ) Interest rate and foreign currency derivative liabilities Derivatives designated as hedging instruments — (2 ) — — (2 ) — (2 ) — — (2 ) Economic hedges (1 ) (8 ) — — (9 ) (1 ) (8 ) — — (9 ) Effect of netting and allocation of collateral 2 5 — — 7 2 5 — — 7 Interest rate and foreign currency derivative liabilities subtotal 1 (5 ) — — (4 ) 1 (5 ) — — (4 ) Deferred compensation obligation — (38 ) — — (38 ) — (145 ) — — (145 ) Total liabilities (63 ) (222 ) (138 ) — (423 ) (63 ) (329 ) (394 ) — (786 ) Total net assets $ 6,322 $ 3,507 $ 1,249 $ 3,534 $ 14,612 $ 6,917 $ 3,464 $ 1,015 $ 3,534 $ 14,930 __________ (a) Generation excludes cash of $283 million and $259 million at December 31, 2018 and 2017 and restricted cash of $39 million and $127 million at December 31, 2018 and 2017 . Exelon excludes cash of $458 million and $389 million at December 31, 2018 and 2017 and restricted cash of $80 million and $145 million at December 31, 2018 and 2017 and includes long-term restricted cash of $185 million and $85 million at December 31, 2018 and 2017 , which is reported in Other deferred debits in the Consolidated Balance Sheets. (b) Includes $50 million and $77 million of cash received from outstanding repurchase agreements at December 31, 2018 and 2017 , respectively, and is offset by an obligation to repay upon settlement of the agreement as discussed in (d) below. (c) Includes derivative instruments of $44 million and less than $1 million , which have a total notional amount of $1,432 million and $811 million at December 31, 2018 and 2017 , respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the fiscal years ended and do not represent the amount of the company's exposure to credit or market loss. (d) Excludes net liabilities of $130 million and $82 million at December 31, 2018 and 2017 , respectively. These items consist of receivables related to pending securities sales, interest and dividend receivables, repurchase agreement obligations, and payables related to pending securities purchases. The repurchase agreements are generally short-term in nature with durations generally of 30 days or less. (e) Excludes net assets of less than $1 million at December 31, 2018 and 2017 . These items consist of receivables related to pending securities sales, interest and dividend receivables, and payables related to pending securities purchases. (f) The amount of unrealized gains/(losses) at Generation totaled less than $1 million and $1 million for the years ended December 31, 2018 and 2017 , respectively. The amount of unrealized gains/(losses) at Exelon totaled $1 million for the years ended December 31, 2018 and 2017 , respectively. (g) Collateral posted/(received) from counterparties totaled $57 million , $224 million and $76 million allocated to Level 1, Level 2 and Level 3 mark-to-market derivatives, respectively, as of December 31, 2018 . Collateral posted/(received) from counterparties totaled $65 million , $320 million and $81 million allocated to Level 1, Level 2 and Level 3 mark-to-market derivatives, respectively, as of December 31, 2017 . (h) Of the collateral posted/(received), $(94) million and $(117) million represents variation margin on the exchanges as of December 31, 2018 and 2017 , respectively. Exelon and Generation hold investments without readily determinable fair values with carrying amounts of $72 million as of December 31, 2018 . Changes were immaterial in fair value, cumulative adjustments and impairments for the year ended December 31, 2018 . ComEd, PECO and BGE The following tables present assets and liabilities measured and recorded at fair value in ComEd's, PECO's and BGE's Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of December 31, 2018 and 2017 : ComEd PECO BGE As of December 31, 2018 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Cash equivalents (a) $ 209 $ — $ — $ 209 $ 111 $ — $ — $ 111 $ 4 $ — $ — $ 4 Rabbi trust investments Mutual funds — — — — 7 — — 7 6 — — 6 Life insurance contracts — — — — — 10 — 10 — — — — Rabbi trust investments subtotal (b) — — — — 7 10 — 17 6 — — 6 Total assets 209 — — 209 118 10 — 128 10 — — 10 Liabilities Deferred compensation obligation — (6 ) — (6 ) — (10 ) — (10 ) — (5 ) — (5 ) Mark-to-market derivative liabilities (c) — — (249 ) (249 ) — — — — — — — — Total liabilities — (6 ) (249 ) (255 ) — (10 ) — (10 ) — (5 ) — (5 ) Total net assets (liabilities) $ 209 $ (6 ) $ (249 ) $ (46 ) $ 118 $ — $ — $ 118 $ 10 $ (5 ) $ — $ 5 ComEd PECO BGE As of December 31, 2017 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Cash equivalents (a) $ 98 $ — $ — $ 98 $ 228 $ — $ — $ 228 $ — $ — $ — $ — Rabbi trust investments Mutual funds — — — — 7 — — 7 6 — — 6 Life insurance contracts — — — — — 10 — 10 — — — — Rabbi trust investments subtotal (b) — — — — 7 10 — 17 6 — — 6 Total assets 98 — — 98 235 10 — 245 6 — — 6 Liabilities Deferred compensation obligation — (8 ) — (8 ) — (11 ) — (11 ) — (5 ) — (5 ) Mark-to-market derivative liabilities (c) — — (256 ) (256 ) — — — — — — — — Total liabilities — (8 ) (256 ) (264 ) — (11 ) — (11 ) — (5 ) — (5 ) Total net assets (liabilities) $ 98 $ (8 ) $ (256 ) $ (166 ) $ 235 $ (1 ) $ — $ 234 $ 6 $ (5 ) $ — $ 1 __________ (a) ComEd excludes cash of $93 million and $45 million at December 31, 2018 and 2017 and restricted cash of $28 million at December 31, 2018 and includes long-term restricted cash of $166 million and $62 million at December 31, 2018 and December 31, 2017 , which is reported in Other deferred debits in the Consolidated Balance Sheets. PECO excludes cash of $24 million and $47 million at December 31, 2018 and 2017 . BGE excludes cash of $7 million and $17 million at December 31, 2018 and 2017 and restricted cash of $2 million and $1 million at December 31, 2018 and December 31, 2017 . (b) The amount of unrealized gains/(losses) at ComEd, PECO and BGE totaled less than $1 million for the years ended December 31, 2018 and December 31, 2017 . (c) The Level 3 balance consists of the current and noncurrent liability of $26 million and $223 million , respectively, at December 31, 2018 , and $21 million and $235 million , respectively, at December 31, 2017 , related to floating-to-fixed energy swap contracts with unaffiliated suppliers. PHI, Pepco, DPL and ACE The following tables present assets and liabilities measured and recorded at fair value in PHI's, Pepco's, DPL's and ACE's Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of December 31, 2018 and 2017 : As of December 31, 2018 As of December 31, 2017 PHI Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Cash equivalents (a) $ 147 $ — $ — $ 147 $ 83 $ — $ — $ 83 Rabbi trust investments Cash equivalents 42 — — 42 72 — — 72 Mutual Funds 13 — — 13 — — — — Fixed income — 15 — 15 — 12 — 12 Life insurance contracts — 22 38 60 — 23 22 45 Rabbi trust investments subtotal (b) 55 37 38 130 72 35 22 129 Total assets 202 37 38 277 155 35 22 212 Liabilities Deferred compensation obligation — (21 ) — (21 ) — (25 ) — (25 ) Mark-to-market derivative liabilities — — — — (1 ) — — (1 ) Effect of netting and allocation of collateral — — — — 1 — — 1 Mark-to-market derivative liabilities subtotal — — — — — — — — Total liabilities — (21 ) — (21 ) — (25 ) — (25 ) Total net assets $ 202 $ 16 $ 38 $ 256 $ 155 $ 10 $ 22 $ 187 Pepco DPL ACE As of December 31, 2018 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Cash equivalents (a) $ 38 $ — $ — $ 38 $ 16 $ — $ — $ 16 $ 23 $ — $ — $ 23 Rabbi trust investments Cash equivalents 41 — — 41 — — — — — — — — Fixed income — 5 — 5 — — — — — — — — Life insurance contracts — 22 37 59 — — — — — — — — Rabbi trust investments subtotal (b) 41 27 37 105 — — — — — — — — Total assets 79 27 37 143 16 — — 16 23 — — 23 Liabilities Deferred compensation obligation — (3 ) — (3 ) — (1 ) — (1 ) — — — — Total liabilities — (3 ) — (3 ) — (1 ) — (1 ) — — — — Total net assets (liabilities) $ 79 $ 24 $ 37 $ 140 $ 16 $ (1 ) $ — $ 15 $ 23 $ — $ — $ 23 Pepco DPL ACE As of December 31, 2017 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Cash equivalents (a) $ 36 $ — $ — $ 36 $ — $ — $ — $ — $ 29 $ — $ — $ 29 Rabbi trust investments Cash equivalents 44 — — 44 — — — — — — — — Fixed income — 12 — 12 — — — — — — — — Life insurance contracts — 23 22 45 — — — — — — — — Rabbi trust investments subtotal (b) 44 35 22 101 — — — — — — — — Total assets 80 35 22 137 — — — — 29 — — 29 Liabilities Deferred compensation obligation — (4 ) — (4 ) — (1 ) — (1 ) — — — — Mark-to-market derivative liabilities — — — — (1 ) — — (1 ) — — — — Effect of netting and allocation of collateral — — — — 1 — — 1 — — — — Mark-to-market derivative liabilities subtotal — — — — — — — — — — — — Total liabilities — (4 ) — (4 ) — (1 ) — (1 ) — — — — Total net assets (liabilities) $ 80 $ 31 $ 22 $ 133 $ — $ (1 ) $ — $ (1 ) $ 29 $ — $ — $ 29 __________ (a) PHI excludes cash of $39 million and $12 million at December 31, 2018 and 2017 and includes long term restricted cash of $19 million and $23 million at December 31, 2018 and 2017 which is reported in Other deferred debits in the Consolidated Balance Sheets. Pepco excludes cash of $15 million and $4 million at December 31, 2018 and 2017 . DPL excludes cash of $8 million and $2 million at December 31, 2018 and 2017 . ACE excludes cash of $7 million and $2 million at December 31, 2018 and 2017 and includes long-term restricted cash of $19 million and $23 million at December 31, 2018 and 2017 at December 31, 2018 and 2017 which is reported in Other deferred debits in the Consolidated Balance Sheets. (b) The amount of unrealized gains/(losses) at PHI totaled $1 million for the years ended December 31, 2018 and 2017 , respectively. The amount of unrealized gains/(losses) at Pepco totaled less than $1 million for the years ended December 31, 2018 and 2017 , respectively. The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis during the years ended December 31, 2018 and 2017 : Generation ComEd PHI Exelon For the year ended December 31, 2018 NDT Fund Investments Pledged Assets Mark-to-Market Other Total Generation Mark-to-Market Derivatives Life Insurance Contracts (c) Eliminated in Consolidation Total Balance as of January 1, 2018 $ 648 $ 12 $ 552 $ 37 $ 1,249 $ (256 ) $ 22 $ — $ 1,015 Total realized / unrealized gains (losses) Included in net income — — (105 ) (a) 3 (102 ) — 4 — (98 ) Included in noncurrent payables to affiliates (1 ) — — — (1 ) — — 1 — Included in payable for Zion Station decommissioning — 7 — — 7 — — — 7 Included in regulatory assets/liabilities — — — — — 7 (b) — (1 ) 6 Change in collateral — — (5 ) — (5 ) — — — (5 ) Purchases, sales, issuances and settlements Purchases 36 1 190 (e) 4 231 — — — 231 Sales — (20 ) (4 ) — (24 ) — — — (24 ) Issuances — — — — — — — — — Settlements (140 ) — 5 — (135 ) — 12 — (123 ) Transfers into Level 3 — — (22 ) (d) — (22 ) — — — (22 ) Transfers out of Level 3 — — (36 ) (d) (2 ) (38 ) — — — (38 ) Other miscellaneous — — — — — — — — Balance as of December 31, 2018 $ 543 $ — $ 575 $ 42 $ 1,160 $ (249 ) $ 38 $ — $ 949 The amount of total (losses) gains included in income attributed to the change in unrealized (losses) gains related to assets and liabilities held as of December 31, 2018 $ (5 ) $ — $ 165 $ 3 $ 163 $ — $ — $ — $ 163 Generation ComEd PHI Exelon For the year ended December 31, 2017 NDT Fund Investments Pledged Assets for Zion Station Decommissioning Mark-to-Market Derivatives Other Investments Total Generation Mark-to-Market Derivatives Life Insurance Contracts (c) Eliminated in Consolidation Total Balance as of January 1, 2017 $ 677 $ 19 $ 493 $ 42 $ 1,231 $ (258 ) $ 20 $ — $ 993 Total realized / unrealized gains (losses) Included in net income 3 — (90 ) (a) 3 (84 ) — 3 — (81 ) Included in noncurrent payables to affiliates 6 — — — 6 — — (6 ) — Included in payable for Zion Station decommissioning — (8 ) — — (8 ) — — (8 ) Included in regulatory assets/liabilities — — — — — 2 (b) — 6 8 Change in collateral — — 20 — 20 — — — 20 Purchases, sales, issuances and settlements Purchases 64 1 178 5 248 — — — 248 Sales — — (16 ) — (16 ) — — — (16 ) Issuances — — — — — — (1 ) — (1 ) Settlements (102 ) — (8 ) — (110 ) — — — (110 ) Transfers into Level 3 — — (6 ) (d) — (6 ) — — — (6 ) Transfers out of Level 3 — — (50 ) (d) (11 ) (61 ) — — — (61 ) Other miscellaneous $ — $ — $ 31 $ (2 ) $ 29 $ — $ — $ — $ 29 Balance as of December 31, 2017 $ 648 $ 12 $ 552 $ 37 $ 1,249 $ (256 ) $ 22 $ — $ 1,015 The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities held as of December 31, 2017 $ 1 $ — $ 254 $ 3 $ 258 $ — $ 3 $ — $ 261 __________ (a) Includes a reduction for the reclassification of $265 million and $352 million of realized gains due to the settlement of derivative contracts for the years ended December 31, 2018 and 2017 , respectively. (b) Includes $24 million of decreases in fair value and an increase for realized losses due to settlements of $17 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2018 . Includes $18 million of decreases in fair value and an increase for realized losses due to settlements of $20 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2017 . (c) The amounts represented are life insurance contracts at Pepco. (d) Transfers into and out of Level 3 generally occur when the contract tenor becomes less and more observable respectively, primarily due to changes in market liquidity or assumptions for certain commodity contracts. (e) Includes $(19) million of fair value from contracts acquired as a result of the Everett Marine Terminal acquisition The following tables present the income statement classification of the total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis during the years ended December 31, 2018 and 2017 : Generation PHI Exelon Operating Revenues Purchased Power and Fuel Other, net Operating and Operating Revenues Purchased Power an |
Derivative Financial Instrument
Derivative Financial Instruments (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivative Financial Instruments (All Registrants) | Derivative Financial Instruments (All Registrants) The Registrants use derivative instruments to manage commodity price risk, interest rate risk and foreign exchange risk related to ongoing business operations. Commodity Price Risk (All Registrants) To the extent the amount of energy Generation produces differs from the amount of energy it has contracted to sell, Exelon and Generation are exposed to market fluctuations in the prices of electricity, fossil fuels and other commodities. Each of the Registrants employ established policies and procedures to manage their risks associated with market fluctuations in commodity prices by entering into physical and financial derivative contracts, including swaps, futures, forwards, options and short-term and long-term commitments to purchase and sell energy and commodity products. The Registrants believe these instruments, which are either determined to be non-derivative or classified as economic hedges, mitigate exposure to fluctuations in commodity prices. Derivative authoritative guidance requires that derivative instruments be recognized as either assets or liabilities at fair value, with changes in fair value of the derivative recognized in earnings immediately. Other accounting treatments are available through special election and designation, provided they meet specific, restrictive criteria both at the time of designation and on an ongoing basis. These alternative permissible accounting treatments include normal purchase normal sale (NPNS), cash flow hedges and fair value hedges. For Generation, all derivative economic hedges related to commodities are recorded at fair value through earnings for the consolidated company, referred to as economic hedges in the following tables. Additionally, Generation is exposed to certain market risks through its proprietary trading activities. The proprietary trading activities are a complement to Generation’s energy marketing portfolio but represent a small portion of Generation’s overall energy marketing activities. Fair value authoritative guidance and disclosures about offsetting assets and liabilities requires the fair value of derivative instruments to be shown in the Combined Notes to Consolidated Financial Statements on a gross basis, even when the derivative instruments are subject to legally enforceable master netting agreements and qualify for net presentation in the Consolidated Balance Sheet. A master netting agreement is an agreement between two counterparties that may have derivative and non-derivative contracts with each other providing for the net settlement of all referencing contracts via one payment stream, which takes place as the contracts deliver, when collateral is requested or in the event of default. Generation’s use of cash collateral is generally unrestricted, unless Generation is downgraded below investment grade (i.e., to BB+ or Ba1). In the table below, Generation’s energy-related economic hedges and proprietary trading derivatives are shown gross. The impact of the netting of fair value balances with the same counterparty that are subject to legally enforceable master netting agreements, as well as netting of cash collateral, including margin on exchange positions, is aggregated in the collateral and netting column. As of December 31, 2018 , $2 million of cash collateral posted with external counterparties and an additional $12 million of cash collateral posted with ComEd, and as of December 31, 2017 , $4 million of cash collateral held, was not offset against derivative positions because such collateral was not associated with any energy-related derivatives, were associated with accrual positions, or had no positions to offset as of the balance sheet date. Excluded from the tables below are economic hedges that qualify for the NPNS scope exception and other non-derivative contracts that are accounted for under the accrual method of accounting. ComEd’s use of cash collateral is generally unrestricted unless ComEd is downgraded below investment grade (i.e., to BB+ or Ba1). Cash collateral held by PECO and BGE must be deposited in an unaffiliated major U.S. commercial bank or foreign bank with a U.S. branch office that meet certain qualifications. In the table below, DPL's economic hedges are shown gross. The impact of the netting of fair value balances with the same counterparty that are subject to legally enforceable master netting agreements, as well as netting of cash collateral, including margin on exchange positions, is aggregated in the collateral and netting column. The following table provides a summary of the derivative fair value balances related to commodity contracts recorded by the Registrants as of December 31, 2018 : Generation ComEd Exelon Description Economic Hedges Proprietary Trading Collateral and Netting (a)(d) Subtotal (b) Economic Hedges (c) Total Derivatives Mark-to-market derivative assets (current assets) $ 3,505 $ 105 $ (2,809 ) $ 801 $ — $ 801 Mark-to-market derivative assets (noncurrent assets) 1,266 41 (862 ) 445 — 445 Total mark-to-market derivative assets 4,771 146 (3,671 ) 1,246 — 1,246 Mark-to-market derivative liabilities (current liabilities) (3,429 ) (74 ) 3,056 (447 ) (26 ) (473 ) Mark-to-market derivative liabilities (noncurrent liabilities) (1,203 ) (20 ) 972 (251 ) (223 ) (474 ) Total mark-to-market derivative liabilities (4,632 ) (94 ) 4,028 (698 ) (249 ) (947 ) Total mark-to-market derivative net assets (liabilities) $ 139 $ 52 $ 357 $ 548 $ (249 ) $ 299 __________ (a) Exelon and Generation net all available amounts allowed under the derivative authoritative guidance on the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases, Exelon and Generation may have other offsetting exposures, subject to a master netting or similar agreement, such as trade receivables and payables, transactions that do not qualify as derivatives, letters of credit and other forms of non-cash collateral. These are not reflected in the table above. (b) Current and noncurrent assets are shown net of collateral of $121 million and $51 million , respectively, and current and noncurrent liabilities are shown net of collateral of $125 million and $60 million , respectively. The total cash collateral posted, net of cash collateral received and offset against mark-to-market assets and liabilities was $357 million at December 31, 2018 . (c) Includes current and noncurrent liabilities relating to floating-to-fixed energy swap contracts with unaffiliated suppliers. (d) Of the collateral posted/(received), $(94) million represents variation margin on the exchanges. The following table provides a summary of the derivative fair value balances related to commodity contracts recorded by the Registrants as of December 31, 2017 : Generation ComEd Exelon Description Economic Hedges Proprietary Trading Collateral and Netting (a)(d) Subtotal (b) Economic Hedges (c) Total Derivatives Mark-to-market derivative assets (current assets) $ 3,061 $ 56 $ (2,144 ) $ 973 $ — $ 973 Mark-to-market derivative assets (noncurrent assets) 1,164 12 (845 ) 331 — 331 Total mark-to-market derivative assets 4,225 68 (2,989 ) 1,304 — 1,304 Mark-to-market derivative liabilities (current liabilities) (2,646 ) (43 ) 2,480 (209 ) (21 ) (230 ) Mark-to-market derivative liabilities (noncurrent liabilities) (1,137 ) (10 ) 975 (172 ) (235 ) (407 ) Total mark-to-market derivative liabilities (3,783 ) (53 ) 3,455 (381 ) (256 ) (637 ) Total mark-to-market derivative net assets (liabilities) $ 442 $ 15 $ 466 $ 923 $ (256 ) $ 667 __________ (a) Exelon and Generation net all available amounts allowed under the derivative authoritative guidance on the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases, Exelon and Generation may have other offsetting exposures, subject to a master netting or similar agreement, such as trade receivables and payables, transactions that do not qualify as derivatives, and letters of credit and other forms of non-cash collateral. These are not reflected in the table above. (b) Current and noncurrent assets are shown net of collateral of $169 million and $53 million , respectively, and current and noncurrent liabilities are shown net of collateral of $167 million and $77 million , respectively. The total cash collateral posted, net of cash collateral received and offset against mark-to-market assets and liabilities was $466 million at December 31, 2017 . (c) Includes current and noncurrent liabilities relating to floating-to-fixed energy swap contracts with unaffiliated suppliers. (d) Of the collateral posted/(received), $(117) million represents variation margin on the exchanges. Economic Hedges (Commodity Price Risk) Within Exelon, Generation has the most exposure to commodity price risk. As such, Generation uses a variety of derivative and non-derivative instruments to manage the commodity price risk of its electric generation facilities, including power and gas sales, fuel and power purchases, natural gas transportation and pipeline capacity agreements and other energy-related products marketed and purchased. To manage these risks, Generation may enter into fixed-price derivative or non-derivative contracts to hedge the variability in future cash flows from expected sales of power and gas and purchases of power and fuel. The objectives for executing such hedges include fixing the price for a portion of anticipated future electricity sales at a level that provides an acceptable return. Generation is also exposed to differences between the locational settlement prices of certain economic hedges and the hedged generating units. This price difference is actively managed through other instruments which include derivative congestion products, whose changes in fair value are recognized in earnings each period, and auction revenue rights, which are accounted for on an accrual basis. For the years ended December 31, 2018 , 2017 and 2016 , Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses) which are also located in the "Net fair value changes related to derivatives" in the Consolidated Statements of Cash Flows. For the Years Ended December 31, 2018 2017 2016 Income Statement Location Gain (Loss) Operating revenues $ (270 ) $ (126 ) $ (490 ) Purchased power and fuel (47 ) (43 ) 459 Total Exelon and Generation $ (317 ) $ (169 ) $ (31 ) In general, increases and decreases in forward market prices have a positive and negative impact, respectively, on Generation’s owned and contracted generation positions that have not been hedged. Generation hedges commodity price risk on a ratable basis over three-year periods. As of December 31, 2018 , the percentage of expected generation hedged for the Mid-Atlantic, Midwest, New York and ERCOT reportable segments is 89% - 92% , 56% - 59% and 32% - 35% for 2019 , 2020 and 2021 , respectively. On December 17, 2010, ComEd executed several 20 -year floating-to-fixed energy swap contracts with unaffiliated suppliers for the procurement of long-term renewable energy and associated RECs. Delivery under the contracts began in June 2012. These contracts are designed to lock in a portion of the long-term commodity price risk resulting from the renewable energy resource procurement requirements in the Illinois Settlement Legislation. ComEd has not elected hedge accounting for these derivative financial instruments. ComEd records the fair value of the swap contracts on its balance sheet. Because ComEd receives full cost recovery for energy procurement and related costs from retail customers, the change in fair value each period is recorded by ComEd as a regulatory asset or liability. See Note 4 — Regulatory Matters for additional information. PECO’s natural gas procurement policy is designed to achieve a reasonable balance of long-term and short-term gas purchases under different pricing approaches to achieve system supply reliability at the least cost. PECO’s reliability strategy is two-fold. First, PECO must assure that there is sufficient transportation capacity to satisfy delivery requirements. Second, PECO must ensure that a firm source of supply exists to utilize the capacity resources. All of PECO’s natural gas supply and asset management agreements that are derivatives either qualify for the NPNS scope exception and have been designated as such, or have no mark-to-market balances because the derivatives are index priced. Additionally, in accordance with the 2018 PAPUC PGC settlement and to reduce the exposure of PECO and its customers to natural gas price volatility, PECO has continued its program to purchase natural gas for both winter and summer supplies using a layered approach of locking-in prices ahead of each season with long-term gas purchase agreements (those with primary terms of at least twelve months). Under the terms of the 2018 and previous PGC settlements, PECO is required to lock in (i.e., economically hedge) the price of a minimum volume of its long-term gas commodity purchases. PECO’s gas-hedging program is designed to cover about 20% of planned natural gas purchases in support of projected firm sales. The hedging program for natural gas procurement has no direct impact on PECO’s results of operations and financial position as natural gas costs are fully recovered from customers under the PGC. BGE has contracts to procure SOS electric supply that are executed through a competitive procurement process approved by the MDPSC. The SOS rates charged recover BGE’s wholesale power supply costs and include an administrative fee. BGE’s commodity price risk related to electric supply procurement is limited. BGE locks in fixed prices for all of its SOS requirements through full requirements contracts. Certain of BGE’s full requirements contracts, which are considered derivatives, qualify for the NPNS scope exception under current derivative authoritative guidance. Other BGE full requirements contracts are not derivatives. BGE provides natural gas to its customers under a MBR mechanism approved by the MDPSC. Under this mechanism, BGE’s actual cost of gas is compared to a market index (a measure of the market price of gas in a given period). The difference between BGE’s actual cost and the market index is shared equally between shareholders and customers. BGE must also secure fixed price contracts for at least 10% , but not more than 20% , of forecasted system supply requirements for flowing (i.e., non-storage) gas for the November through March period. These fixed-price contracts are not subject to sharing under the MBR mechanism. BGE also ensures it has sufficient pipeline transportation capacity to meet customer requirements. BGE’s natural gas supply and asset management agreements qualify for the NPNS scope exception and result in physical delivery. Pepco has contracts to procure SOS electric supply that are executed through a competitive procurement process approved by the MDPSC and DCPSC. The SOS rates charged recover Pepco's wholesale power supply costs and include an administrative fee. The administrative fee includes an incremental cost component and a shareholder return component for residential and commercial rate classes. Pepco’s commodity price risk related to electric supply procurement is limited. Pepco locks in fixed prices for its SOS requirements through full requirements contracts. Certain of Pepco’s full requirements contracts, which are considered derivatives, qualify for the NPNS scope exception under current derivative authoritative guidance. Other Pepco full requirements contracts are not derivatives. DPL has contracts to procure SOS electric supply that are executed through a competitive procurement process approved by the MDPSC and the DPSC. The SOS rates charged recover DPL's wholesale power supply costs. In Delaware, DPL is also entitled to recover a Reasonable Allowance for Retail Margin (RARM). The RARM includes a fixed annual margin of approximately $2.75 million , plus an incremental cost component and a cash working capital allowance. In Maryland, DPL charges an administrative fee intended to allow it to recover its administrative costs. DPL locks in fixed prices for its SOS requirements through full requirements contracts. DPL’s commodity price risk related to electric supply procurement is limited. Certain of DPL’s full requirements contracts, which are considered derivatives, qualify for the NPNS scope exception under current derivative authoritative guidance. Other DPL full requirements contracts are not derivatives. DPL provides natural gas to its customers under an Annual GCR mechanism approved by the DPSC. Under this mechanism, DPL’s Annual GCR Filing establishes a future GCR for firm bundled sales customers by using a forecast of demand and commodity costs. The actual costs are trued up against forecast on a monthly basis and any shortfall or excess is carried forward as a recovery balance in the next GCR filing. The demand portion of the GCR is based upon DPL’s firm transportation and storage contracts. DPL has firm deliverability of swing and seasonal storage; a liquefied natural gas facility and firm transportation capacity to meet customer demand and provide a reserve margin. The commodity portion of the GCR includes a commission approved hedging program which is intended to reduce gas commodity price volatility while limiting the firm natural gas customers’ exposure to adverse changes in the market price of natural gas. The hedge program requires that DPL hedge, on a non-discretionary basis, an amount equal to 50% of estimated purchase requirements for each month, including estimated monthly purchases for storage injections. The 50% hedge monthly target is achieved by hedging 1/12th of the 50% target each month beginning 12-months prior to the month in which the physical gas is to be purchased. Currently, DPL uses only exchange traded futures for its gas hedging program, which are considered derivatives, however, it retains the capability to employ other physical and financial hedges if needed. DPL has not elected hedge accounting for these derivative financial instruments. Because of the DPSC-approved fuel adjustment clause for DPL's derivatives, the change in fair value of the derivatives each period, in addition to all premiums paid and other transaction costs incurred as part of the Gas Hedging Program, are fully recoverable and are recorded by DPL as regulatory assets or liabilities. DPL’s physical gas purchases are currently all daily, monthly or intra-month transactions. From time to time, DPL will enter into seasonal purchase or sale arrangements, however, there are none currently in the portfolio. Certain of DPL's full requirements contracts, which are considered derivatives, qualify for the NPNS scope exception under current derivative authoritative guidance. Other DPL full requirements contracts are not derivatives. ACE has contracts to procure BGS electric supply that are executed through a competitive procurement process approved by the NJBPU. The BGS rates charged recover ACE's wholesale power supply costs. ACE does not make any profit or incur any loss on the supply component of the BGS it supplies to customers. ACE’s commodity price risk related to electric supply procurement is limited. ACE locks in fixed prices for its BGS requirements through full requirements contracts. Certain of ACE’s full requirements contracts, which are considered derivatives, qualify for the NPNS scope exception under current derivative authoritative guidance. Other ACE full requirements contracts are not derivatives. Proprietary Trading (Commodity Price Risk) Generation also executes commodity derivatives for proprietary trading purposes. Proprietary trading includes all contracts executed with the intent of benefiting from shifts or changes in market prices as opposed to those executed with the intent of hedging or managing risk. Proprietary trading activities are subject to limits established by Exelon’s RMC. The proprietary trading portfolio is subject to a risk management policy that includes stringent risk management limits to manage exposure to market risk. Additionally, the Exelon risk management group and Exelon's RMC monitor the financial risks of the proprietary trading activities. The proprietary trading activities are a complement to Generation's energy marketing portfolio but represent a small portion of Generation's overall revenue from energy marketing activities. Gains and losses associated with proprietary trading are reported as Operating revenues in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. For the years ended December 31, 2018 , 2017 and 2016 , Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses) which are also included in the "Net fair value changes related to derivatives" in the Consolidated Statements of Cash Flows. The Utility Registrants do not execute derivatives for proprietary trading purposes. For the Years Ended December 31, 2018 2017 2016 Income Statement Location Gain Operating revenues $ 17 $ 6 $ 2 Interest Rate and Foreign Exchange Risk (All Registrants) The Registrants use a combination of fixed-rate and variable-rate debt to manage interest rate exposure. The Registrants also utilize interest rate swaps, which are treated as economic hedges, to manage their interest rate exposure. To manage foreign exchange rate exposure associated with international commodity purchases in currencies other than U.S. dollars, Generation utilizes foreign currency derivatives, which are treated as economic hedges. Below is a summary of the interest rate and foreign exchange hedge balances as of December 31, 2018 : Generation Exelon Corporate Exelon Description Economic Hedges Collateral and Netting (a) Subtotal Economic Total Mark-to-market derivative assets (current assets) $ 5 $ (2 ) $ 3 $ — $ 3 Mark-to-market derivative assets (noncurrent assets) 8 (1 ) 7 — 7 Total mark-to-market derivative assets 13 (3 ) 10 — 10 Mark-to-market derivative liabilities (current liabilities) (4 ) 2 (2 ) — (2 ) Mark-to-market derivative liabilities (noncurrent liabilities) (2 ) 1 (1 ) (4 ) (5 ) Total mark-to-market derivative liabilities (6 ) 3 (3 ) (4 ) (7 ) Total mark-to-market derivative net assets (liabilities) $ 7 $ — $ 7 $ (4 ) $ 3 __________ (a) Exelon and Generation net all available amounts allowed under the derivative authoritative guidance on the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases, Exelon and Generation may have other offsetting counterparty exposures subject to a master netting or similar agreement, such as accrued interest, transactions that do not qualify as derivatives, letters of credit and other forms of non-cash collateral, which are not reflected in the table above. The following table provides a summary of the interest rate and foreign exchange hedge balances recorded by the Registrants as of December 31, 2017 : Generation Exelon Corporate Exelon Description Derivatives Designated as Hedging Instruments Economic Hedges Collateral and Netting (a) Subtotal Derivatives Total Mark-to-market derivative assets (current assets) $ — $ 10 $ (7 ) $ 3 $ — $ 3 Mark-to-market derivative assets (noncurrent assets) 3 — — 3 3 6 Total mark-to-market derivative assets 3 10 (7 ) 6 3 9 Mark-to-market derivative liabilities (current liabilities) (2 ) (7 ) 7 (2 ) — (2 ) Mark-to-market derivative liabilities (noncurrent liabilities) — (2 ) — (2 ) — (2 ) Total mark-to-market derivative liabilities (2 ) (9 ) 7 (4 ) — (4 ) Total mark-to-market derivative net assets (liabilities) $ 1 $ 1 $ — $ 2 $ 3 $ 5 __________ (a) Exelon and Generation net all available amounts allowed under the derivative authoritative guidance on the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases, Exelon and Generation may have other offsetting counterparty exposures subject to a master netting or similar agreement, such as accrued interest, transactions that do not qualify as derivatives, letters of credit and other forms of non-cash collateral, which are not reflected in the table above. Economic Hedges (Interest Rate and Foreign Exchange Risk) Exelon and Generation execute these instruments to mitigate exposure to fluctuations in interest rates or foreign exchange but for which the fair value or cash flow hedge elections were not made. On July 1, 2018, Exelon de-designated its fair value hedges related to interest rate risk and Generation de-designated its cash flow hedges related to interest rate risk. The amount deferred in AOCI associated with the previously designated cash flow hedges will be reclassified into earnings as the underlying forecasted transaction occurs. The result of this de-designation is that all economic hedges for interest rate swaps will be recorded at fair value through earnings going forward, referred to as economic hedges in the following tables. The following table provides notional amounts outstanding held by Exelon and Generation at December 31, 2018 related to interest rate swaps and foreign currency exchange rate swaps. Generation Exelon Corporate Exelon Foreign currency exchange rate swaps $ 268 $ — $ 268 Interest rate swaps 620 800 1,420 Total $ 888 $ 800 $ 1,688 The following table provides notional amounts outstanding held by Exelon and Generation at December 31, 2017 related to interest rate swaps and foreign currency exchange rate swaps. Generation Exelon Corporate Exelon Foreign currency exchange rate swaps $ 94 $ — $ 94 Interest rate swaps (a) 1 — 1 Total $ 95 $ — $ 95 __________ (a) On July 1, 2018, Exelon and Generation de-designated its fair value and cash flow hedges. The table excludes amounts of $800 million of fixed-to-floating hedges that were previously designated as fair value hedges by Exelon and $636 million of floating-to-fixed hedges that were previously designated as cash flow hedges by Exelon and Generation as of December 31, 2017. For the years ended December 31, 2018 , 2017 and 2016 , Exelon and Generation recognized the following net pre-tax mark-to-market gains (losses) in the Consolidated Statements of Operations and Comprehensive Income and are included in “Net fair value changes related to derivatives” in Exelon’s and Generation’s Consolidated Statements of Cash Flows. For the Years Ended December 31, 2018 2017 2016 Income Statement Location Gain (Loss) Generation Operating Revenues $ 7 $ (6 ) $ (10 ) Generation Purchased Power and Fuel (9 ) — — Generation Interest Expense (7 ) (3 ) — Total Generation $ (9 ) $ (9 ) $ (10 ) For the Years Ended December 31, 2018 2017 2016 Income Statement Location Gain (Loss) Exelon Operating Revenues $ 7 $ (6 ) $ (10 ) Exelon Purchased Power and Fuel (9 ) — — Exelon Interest Expense (4 ) (3 ) — Total Exelon $ (6 ) $ (9 ) $ (10 ) Fair Value Hedges (Interest Rate Risk) For derivative instruments that qualify and are designated as fair value hedges, the gain or loss on the derivative as well as the offsetting loss or gain on the hedged item attributable to the hedged risk are recognized in earnings immediately. Exelon had no fixed-to-floating swaps designated as fair value hedges as of December 31, 2018 and had $800 million notional amounts designated as fair value hedges as of December 31, 2017 . Exelon and Generation include the gain or loss on the hedged items and the offsetting loss or gain on the related interest rate swaps as follows: Year Ended December 31, Income Statement Location 2018 2017 2016 2018 2017 2016 Loss on Swaps Gain on Borrowings Exelon Interest expense $ (11 ) $ (13 ) $ (9 ) $ 20 $ 28 $ 23 During the years ended December 31, 2018 , 2017 and 2016 , the impact on the results of operations due to ineffectiveness from fair value hedges were gains of $9 million , $15 million and $14 million , respectively. Cash Flow Hedges (Interest Rate Risk) For derivative instruments that qualify and are designated as cash flow hedges, the gain or loss on the effective portion of the derivative will be deferred in AOCI and reclassified into earnings when the underlying transaction occurs. Exelon and Generation have no floating-to-fixed swaps designated as cash flow hedges as of December 31, 2018 , and had $636 million notional amounts designated as cash flow hedges as of December 31, 2017 . The tables below provide the activity of OCI related to cash flow hedges for the years ended December 31, 2018 and 2017 , containing information about the changes in the fair value of cash flow hedges and the reclassification from AOCI into results of operations. The amounts reclassified from AOCI, when combined with the impacts of the hedged transactions, result in the ultimate recognition of net revenues or expenses at the contractual price. Total Cash Flow Hedge AOCI Activity, Net of Income Tax Generation Exelon For the Year Ended December 31, 2018 Income Statement Location Total Cash Total Cash Flow Hedges AOCI derivative loss at December 31, 2017 $ (16 ) $ (14 ) Effective portion of changes in fair value 11 11 Reclassifications from AOCI to net income Interest expense 1 1 AOCI derivative loss at December 31, 2018 $ (4 ) $ (2 ) Total Cash Flow Hedge AOCI Activity, Net of Income Tax Generation Exelon For the Year Ended December 31, 2017 Income Statement Location Total Cash Total Cash Flow Hedges AOCI derivative loss at December 31, 2016 $ (19 ) $ (17 ) Effective portion of changes in fair value (1 ) (1 ) Reclassifications from AOCI to net income Interest expense 4 (a) 4 (a) AOCI derivative loss at December 31, 2017 $ (16 ) $ (14 ) __________ (a) Amount is net of related income tax expense of $1 million for the year ended December 31, 2017 . During the years ended December 31, 2018 , 2017 and 2016 , the impact on the results of operations as a result of ineffectiveness from cash flow hedges was immaterial. The estimated amount of existing gains and losses that are reported in AOCI at the reporting date that are expected to be reclassified into earnings within the next twelve months is immaterial. Proprietary Trading (Interest Rate and Foreign Exchange Risk) Generation also executes derivative contracts for proprietary trading purposes to hedge risk associated with the interest rate and foreign exchange components of underlying commodity positions. Gains and losses associated with proprietary trading are reported as Operating revenues in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income and are included in “Net fair value changes related to derivatives” in Exelon’s and Generation’s Consolidated Statements of Cash Flows. For the years ended December 31, 2018 , 2017 and 2016 , Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses). For the Years Ended December 31, 2018 2017 2016 Income Statement Location Loss Operating revenues $ — $ (1 ) $ (1 ) Credit Risk, Collateral and Contingent-Related Features (All Registrants) The Registrants would be exposed to credit-related losses in the event of non-performance by counterparties on executed derivative instruments. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date. For commodity derivatives, Generation enters into enabling agreements that allow for payment netting with its counterparties, which reduces Generation’s exposure to counterparty risk by providing for the offset of amounts payable to the counterparty against amounts receivable from the counterparty. Typically, each enabling agreement is for a specific commodity and so, with respect to each individual counterparty, netting is limited to transactions involving that specific commodity product, except where master netting agreements exist with a counterparty that allow for cross product netting. In addition to payment netting language in the enabling agreement, Generation’s credit department establishes credit limits, margining thresholds and collateral requirements for each counterparty, which are defined in the derivative contracts. Counterparty credit limits are based on an internal credit review process that considers a variety of factors, including the results of a s |
Debt and Credit Agreements (All
Debt and Credit Agreements (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Debt Disclosure [Abstract] | |
Debt and Credit Agreements (All Registrants) | Debt and Credit Agreements (All Registrants) Short-Term Borrowings Exelon Corporate, ComEd, BGE, Pepco, DPL and ACE meet their short-term liquidity requirements primarily through the issuance of commercial paper. Generation and PECO meet their short-term liquidity requirements primarily through the issuance of commercial paper and borrowings from the Exelon intercompany money pool. PHI Corporate meets its short-term liquidity requirements primarily through the issuance of short-term notes and the Exelon intercompany money pool. The Registrants may use their respective credit facilities for general corporate purposes, including meeting short-term funding requirements and the issuance of letters of credit. Commercial Paper The following table reflects the Registrants' commercial paper programs supported by the revolving credit agreements and bilateral credit agreements at December 31, 2018 and 2017 : Maximum Program Size at December 31, Outstanding Commercial Paper at December 31, Average Interest Rate on Commercial Paper Borrowings for the Year Ended December 31, Commercial Paper Issuer 2018 (a)(b)(c) 2017 (a)(b)(c) 2018 2017 2018 2017 Exelon Corporate $ 600 $ 600 $ — $ — 1.93 % 1.16 % Generation 5,300 5,300 — — 1.96 % 1.23 % ComEd 1,000 1,000 — — 2.14 % 1.24 % PECO 600 600 — — 2.24 % 1.13 % BGE 600 600 35 77 2.18 % 1.28 % Pepco 300 500 40 26 2.24 % 1.06 % DPL 300 500 — 216 2.07 % 1.48 % ACE 300 350 14 108 2.21 % 1.43 % Total $ 9,000 $ 9,450 $ 89 $ 427 __________ (a) Excludes $545 million and $480 million in bilateral credit facilities at December 31, 2018 and 2017 , respectively, and $159 million and $179 million in credit facilities for project finance at December 31, 2018 and 2017 , respectively. These credit facilities do not back Generation's commercial paper program. (b) At December 31, 2018, excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million , $33 million , $34 million , $5 million , $5 million , $5 million and $5 million , respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. At December 31, 2017, excludes $128 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million , $34 million , $34 million , $5 million , $2 million , $2 million , and $2 million , respectively. (c) Pepco, DPL and ACE's revolving credit facility is subject to available borrowing capacity. The borrowing capacity may be increased or decreased during the term of the facility, except that (i) the sum of the borrowing capacity must equal the total amount of the facility, and (ii) the aggregate amount of credit used at any given time by each of Pepco, DPL or ACE may not exceed $900 million or the maximum amount of short-term debt the company is permitted to have outstanding by its regulatory authorities. The total number of the borrowing reallocations may not exceed eight per year during the term of the facility. In order to maintain their respective commercial paper programs in the amounts indicated above, each Registrant must have credit facilities in place, at least equal to the amount of its commercial paper program. While the amount of outstanding commercial paper does not reduce available capacity under a Registrant’s credit facility, a Registrant does not issue commercial paper in an aggregate amount exceeding the then available capacity under its credit facility. At December 31, 2018 , the Registrants had the following aggregate bank commitments, credit facility borrowings and available capacity under their respective credit facilities: Available Capacity at December 31, 2018 Borrower Facility Type Aggregate Bank (a) Facility Draws Outstanding Letters of Credit Actual To Support Additional Commercial (b) Exelon Corporate Syndicated Revolver $ 600 $ — $ 9 $ 591 $ 591 Generation Syndicated Revolver 5,300 — 1,203 4,097 4,097 Generation Bilaterals 545 — 353 192 — Generation Project Finance 159 — 119 40 — ComEd Syndicated Revolver 1,000 — 2 998 998 PECO Syndicated Revolver 600 — — 600 600 BGE Syndicated Revolver 600 — 1 599 564 Pepco Syndicated Revolver 300 — 8 292 252 DPL Syndicated Revolver 300 — 1 299 299 ACE Syndicated Revolver 300 — — 300 286 Total $ 9,704 $ — $ 1,696 $ 8,008 $ 7,687 __________ (a) Excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million , $33 million , $34 million , $5 million , $5 million , $5 million and $5 million , respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. As of December 31, 2018 , letters of credit issued under these facilities totaled $5 million and $2 million for Generation and BGE, respectively. The following tables present the short-term borrowings activity for Exelon, Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE during 2018 , 2017 and 2016 . Exelon 2018 2017 2016 Average borrowings $ 531 $ 823 $ 1,125 Maximum borrowings outstanding 1,237 2,147 3,076 Average interest rates, computed on a daily basis 2.21 % 1.32 % 0.88 % Average interest rates, at December 31 2.15 % 1.24 % 1.12 % Generation 2018 2017 2016 Average borrowings $ 37 $ 405 $ 536 Maximum borrowings outstanding 583 1,455 1,735 Average interest rates, computed on a daily basis 1.96 % 1.23 % 0.94 % Average interest rates, at December 31 1.96 % 1.23 % 1.14 % ComEd 2018 2017 2016 Average borrowings $ 154 $ 200 $ 256 Maximum borrowings outstanding 520 470 755 Average interest rates, computed on a daily basis 2.14 % 1.24 % 0.77 % Average interest rates, at December 31 2.14 % 1.24 % N/A PECO 2018 2017 2016 Average borrowings $ 68 $ 2 $ — Maximum borrowings outstanding 350 60 — Average interest rates, computed on a daily basis 2.24 % 1.13 % N/A Average interest rates, at December 31 2.24 % 1.13 % N/A BGE 2018 2017 2016 Average borrowings $ 65 $ 54 $ 143 Maximum borrowings outstanding 239 165 369 Average interest rates, computed on a daily basis 2.18 % 1.28 % 0.77 % Average interest rates, computed at December 31 2.18 % 1.28 % 0.95 % PHI Corporate 2018 2017 2016 Average borrowings N/A N/A $ 153 Maximum borrowings outstanding N/A N/A 559 Average interest rates, computed on a daily basis N/A N/A 1.03 % Average interest rates, computed at December 31 N/A N/A N/A Pepco 2018 2017 2016 Average borrowings $ 22 $ 51 $ 4 Maximum borrowings outstanding 90 197 73 Average interest rates, computed on a daily basis 2.24 % 1.06 % 0.71 % Average interest rates, computed at December 31 2.24 % 1.06 % 0.90 % DPL 2018 2017 2016 Average borrowings $ 87 $ 40 $ 33 Maximum borrowings outstanding 245 216 116 Average interest rates, computed on a daily basis 2.07 % 1.48 % 0.68 % Average interest rates, computed at December 31 2.07 % 1.48 % N/A ACE 2018 2017 2016 Average borrowings $ 95 $ 30 $ — Maximum borrowings outstanding 210 133 5 Average interest rates, computed on a daily basis 2.21 % 1.43 % 0.65 % Average interest rates, computed at December 31 2.21 % 1.43 % N/A Short-Term Loan Agreements On January 13, 2016, PHI entered into a $500 million term loan agreement, which was amended on March 28, 2016. The net proceeds of the loan were used to repay PHI's outstanding commercial paper, and for general corporate purposes. Pursuant to the loan agreement, as amended, loans made thereunder bear interest at a variable rate equal to LIBOR plus 1% , and all indebtedness thereunder is unsecured. On March 23, 2017, the aggregate principal amount of all loans, together with any accrued but unpaid interest due under the loan agreement was fully repaid and the loan terminated. On March 23, 2017, Exelon Corporate entered into a similar type term loan for $500 million which expired on March 22, 2018. The loan agreement was renewed on March 22, 2018 and will expire on March 21, 2019. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR plus 1% and all indebtedness thereunder is unsecured. The loan agreement is reflected in Exelon's Consolidated Balance Sheet within Short-Term borrowings. On May 23, 2018, ACE entered into two term loan agreements in the aggregate amount of $ 125 million , which expire on May 22, 2019. Pursuant to the term loan agreements, loans made thereunder bear interest at a variable rate equal to LIBOR plus 0.55% and all indebtedness thereunder is unsecured. Credit Agreements On January 5, 2016, Generation entered into a credit agreement establishing a $150 million bilateral credit facility. On January 4, 2019, the credit agreement was amended to extend its maturity from January 2019 to April 2021. This facility will solely be utilized by Generation to issue lines of credit. This facility does not back Generation's commercial paper program. On April 1, 2016, the credit agreement for CENG's $100 million bilateral credit facility was amended to increase the overall facility size to $200 million , scheduled to mature in October of 2019. This facility is utilized by CENG to fund working capital and capital projects. The facility does not back Generation's commercial paper program. On May 26, 2016, Exelon Corporate, Generation, ComEd, PECO and BGE entered into amendments to each of their respective syndicated revolving credit facilities, which extended the maturity of each of the facilities to May 26, 2021. Exelon Corporate also increased the size of its facility from $500 million to $600 million . On May 26, 2016, PHI, Pepco, DPL and ACE entered into an amendment to their Second Amended and Restated Credit Agreement dated as of August 1, 2011, which (i) extended the maturity date of the facility to May 26, 2021, (ii) removed PHI as a borrower under the facility, (iii) decreased the size of the facility from $1.5 billion to $900 million and (iv) aligned its financial covenant from debt to capitalization leverage ratio to interest coverage ratio. On May 26, 2018, each of the Registrants' respective syndicated revolving credit facilities had their maturity dates extended to May 26, 2023. On January 9, 2017, the credit agreement for Generation's $75 million bilateral credit facility was amended and restated to increase the facility size to $100 million . On January 4, 2019, the credit agreement was amended to extend its maturity from January 2019 to March 2021. This facility will solely be used by Generation to issue letters of credit. On March 15, 2018, the credit agreement for a Generation bilateral credit facility of $30 million was amended to increase the overall facility size to $95 million , scheduled to mature in March of 2020. This facility will solely be used by Generation to issue letters of credit. Borrowings under Exelon Corporate’s, Generation’s, ComEd’s, PECO’s, BGE's, Pepco's, DPL's and ACE's revolving credit agreements bear interest at a rate based upon either the prime rate or a LIBOR-based rate, plus an adder based upon the particular Registrant’s credit rating. The adders for the prime based borrowings and LIBOR-based borrowings are presented in the following table: Exelon Generation ComEd PECO BGE Pepco DPL ACE Prime based borrowings 27.5 27.5 7.5 — — 7.5 7.5 7.5 LIBOR-based borrowings 127.5 127.5 107.5 90.0 100.0 107.5 107.5 107.5 The maximum adders for prime rate borrowings and LIBOR-based rate borrowings are 90 basis points and 165 basis points, respectively. The credit agreements also require the borrower to pay a facility fee based upon the aggregate commitments. The fee varies depending upon the respective credit ratings of the borrower. Each revolving credit agreement for Exelon, Generation, ComEd, PECO, BGE, Pepco, DPL and ACE requires the affected borrower to maintain a minimum cash from operations to interest expense ratio for the twelve-month period ended on the last day of any quarter. The following table summarizes the minimum thresholds reflected in the credit agreements for the year ended December 31, 2018 : Exelon Generation ComEd PECO BGE Pepco DPL ACE Credit agreement threshold 2.50 to 1 3.00 to 1 2.00 to 1 2.00 to 1 2.00 to 1 2.00 to 1 2.00 to 1 2.00 to 1 At December 31, 2018 , the interest coverage ratios at the Registrants were as follows: Exelon Generation ComEd PECO BGE Pepco DPL ACE Interest coverage ratio 7.34 10.99 7.34 8.14 9.77 5.98 7.03 5.06 An event of default under Exelon, Generation, ComEd, PECO or BGE's indebtedness will not constitute an event of default under any of the others’ credit facilities, except that a bankruptcy or other event of default in the payment of principal, premium or indebtedness in principal amount in excess of $100 million in the aggregate by Generation will constitute an event of default under the Exelon Corporate credit facility. An event of default under Pepco, DPL or ACE's indebtedness will not constitute an event of default with respect to the other PHI Utilities under the PHI Utilities' combined credit facility. The absence of a material adverse change in Exelon's or PHI’s business, property, results of operations or financial condition is not a condition to the availability of credit under any of the borrowers' credit agreement. None of the credit agreements include any rating triggers. Variable Rate Demand Bonds DPL has outstanding obligations in respect of Variable Rate Demand Bonds (VRDB). VRDBs are subject to repayment on the demand of the holders and, for this reason, are accounted for as short-term debt in accordance with GAAP. However, bonds submitted for purchase are remarketed by a remarketing agent on a best efforts basis. PHI expects that any bonds submitted for purchase will be remarketed successfully due to the creditworthiness of the issuer and, as applicable, the credit support, and because the remarketing resets the interest rate to the then-current market rate. The bonds may be converted to a fixed-rate, fixed-term option to establish a maturity which corresponds to the date of final maturity of the bonds. On this basis, PHI views VRDBs as a source of long-term financing. As of both December 31, 2018 and December 31, 2017 , $79 million in variable rate demand bonds issued by DPL were outstanding and are included in the Long-term debt due within one year in Exelon's, PHI's and DPL's Consolidated Balance Sheet. Long-Term Debt The following tables present the outstanding long-term debt at the Registrants as of December 31, 2018 and 2017 : Exelon Maturity Date December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 1.70 % - 7.90 % 2019 - 2048 16,496 15,197 Senior unsecured notes 2.45 % - 7.60 % 2019 - 2046 11,285 11,285 Unsecured notes 2.40 % - 6.35 % 2021 - 2048 2,900 2,600 Pollution control notes 2.50 % - 2.70 % 2025 - 2036 435 435 Nuclear fuel procurement contracts 3.15 % 2020 39 82 Notes payable and other (b)(c) 2.85 % - 8.88 % 2019 - 2053 188 405 Junior subordinated notes 3.50 % 2022 1,150 1,150 Long-term software licensing agreement 3.95 % 2024 73 79 Unsecured Tax-Exempt Bonds 1.74 % - 5.40 % — 2024 - 2031 112 112 Medium-Terms Notes (unsecured) 7.61 % - 7.72 % 2019 - 2027 22 26 Transition bonds 5.55 % 2023 59 90 Loan Agreement 2.00 % 2023 50 — Nonrecourse debt: Fixed rates 2.29 % - 6.00 % 2031 - 2037 1,253 1,331 Variable rates (f) 5.81 % 2019 - 2024 849 865 Total long-term debt 34,911 33,657 Unamortized debt discount and premium, net (66 ) (57 ) Unamortized debt issuance costs (216 ) (201 ) Fair value adjustment 795 865 Long-term debt due within one year (e) (1,349 ) (2,088 ) Long-term debt $ 34,075 $ 32,176 Long-term debt to financing trusts (d) Subordinated debentures to ComEd Financing III 6.35 % 2033 $ 206 $ 206 Subordinated debentures to PECO Trust III 7.38 % - 7.50 % 2028 81 81 Subordinated debentures to PECO Trust IV 5.75 % 2033 103 103 Total long-term debt to financing trusts 390 390 Unamortized debt issuance costs — (1 ) Long-term debt to financing trusts $ 390 $ 389 __________ (a) Substantially all of ComEd’s assets other than expressly excepted property and substantially all of PECO’s, Pepco's, DPL's and ACE's assets are subject to the liens of their respective mortgage indentures. (b) Includes capital lease obligations of $36 million and $53 million at December 31, 2018 and 2017 , respectively. Lease payments of $21 million , $5 million , $1 million , $1 million , less than $1 million, and $8 million will be made in 2019 , 2020 , 2021 , 2022 , 2023 , and thereafter, respectively. (c) Includes financing related to Albany Green Energy, LLC (AGE). During the third quarter of 2017, Generation retired $228 million of its outstanding debt balance. (d) Amounts owed to these financing trusts are recorded as Long-term debt to financing trusts within Exelon’s Consolidated Balance Sheets. (e) In January 2019, $300 million of ComEd long-term debt due within one year was paid in full. (f) Excludes interest on CEU Upstream nonrecourse debt, see discussion below. Generation Maturity Date December 31, Rates 2018 2017 Long-term debt Senior unsecured notes 2.95 % - 7.60 % 2019 - 2042 $ 6,019 $ 6,019 Pollution control notes 2.50 % - 2.70 % 2025 - 2036 435 435 Nuclear fuel procurement contracts 3.15 % 2020 39 82 Notes payable and other (a)(b) 2.85 % - 7.83 % 2019 - 2024 164 223 Nonrecourse debt: Fixed rates 2.29 % - 6.00 % 2031 - 2037 1,253 1,331 Variable rates (c) 5.81 % 2019 - 2024 849 865 Total long-term debt 8,759 8,955 Unamortized debt discount and premium, net (6 ) (8 ) Unamortized debt issuance costs (51 ) (60 ) Fair value adjustment 91 103 Long-term debt due within one year (906 ) (346 ) Long-term debt $ 7,887 $ 8,644 __________ (a) Includes Generation’s capital lease obligations of $14 million and $18 million at December 31, 2018 and 2017 , respectively. Generation will make lease payments of $7 million , $5 million , $1 million , and $1 million in 2019 , 2020 , 2021 , and 2022 , respectively. Lease payments of less than $1 million annually will be made from 2023 through expiration of the final capital lease in 2024. (b) Includes financing related to Albany Green Energy, LLC (AGE). During the third quarter of 2017, Generation retired $228 million of its outstanding debt balance. (c) Excludes interest on CEU Upstream nonrecourse debt, see discussion below. ComEd Maturity Date December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 2.15 % - 6.45 % 2019 - 2048 $ 8,179 $ 7,529 Notes payable and other (b) 7.49 % 2053 8 147 Total long-term debt 8,187 7,676 Unamortized debt discount and premium, net (23 ) (23 ) Unamortized debt issuance costs (63 ) (52 ) Long-term debt due within one year (d) (300 ) (840 ) Long-term debt $ 7,801 $ 6,761 Long-term debt to financing trust (c) Subordinated debentures to ComEd Financing III 6.35 % 2033 $ 206 $ 206 Total long-term debt to financing trusts 206 206 Unamortized debt issuance costs (1 ) (1 ) Long-term debt to financing trusts $ 205 $ 205 __________ (a) Substantially all of ComEd’s assets, other than expressly excepted property, are subject to the lien of its mortgage indenture. (b) Includes ComEd’s capital lease obligations of $8 million at both December 31, 2018 and 2017 , respectively. Lease payments of less than $1 million annually will be made from 2019 through expiration at 2053. (c) Amount owed to this financing trust is recorded as Long-term debt to financing trust within ComEd’s Consolidated Balance Sheets. (d) In January 2019, the $300 million balance was paid in full. PECO Maturity Date December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 1.70 % - 5.95 % 2021 - 2048 $ 3,075 $ 2,925 Loan Agreement 2.00 % 2023 50 0 Total long-term debt 3,125 2,925 Unamortized debt discount and premium, net (18 ) (5 ) Unamortized debt issuance costs (23 ) (17 ) Long-term debt due within one year — (500 ) Long-term debt $ 3,084 $ 2,403 Long-term debt to financing trusts (b) Subordinated debentures to PECO Trust III 7.38 % - 7.50 % 2028 $ 81 $ 81 Subordinated debentures to PECO Trust IV 5.75 % 2033 103 103 Long-term debt to financing trusts $ 184 $ 184 __________ (a) Substantially all of PECO’s assets are subject to the lien of its mortgage indenture. (b) Amounts owed to this financing trust are recorded as Long-term debt to financing trusts within PECO’s Consolidated Balance Sheets. BGE Maturity Date December 31, Rates 2018 2017 Long-term debt Unsecured notes 2.40 % - 6.35 % 2021 - 2048 2,900 2,600 Total long-term debt 2,900 2,600 Unamortized debt discount and premium, net (6 ) (6 ) Unamortized debt issuance costs (18 ) (17 ) Long-term debt $ 2,876 $ 2,577 PHI Maturity December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 1.81 % - 7.90 % 2021 - 2048 $ 5,242 $ 4,743 Senior unsecured notes 7.45 % 2032 185 185 Unsecured Tax-Exempt Bonds 1.74 % - 5.40 % 2024 - 2031 112 112 Medium-terms notes (unsecured) 7.61 % - 7.72 % 2019 - 2027 22 26 Transition bonds (b) 5.55 % 2023 59 90 Notes payable and other (c) 7.28 % - 8.88 % 2019 - 2022 16 33 Total long-term debt 5,636 5,189 Unamortized debt discount and premium, net 4 5 Unamortized debt issuance costs (14 ) (6 ) Fair value adjustment 633 686 Long-term debt due within one year (125 ) (396 ) Long-term debt $ 6,134 $ 5,478 __________ (a) Substantially all of Pepco's, DPL's, and ACE's assets are subject to the lien of its respective mortgage indenture. (b) Transition bonds are recorded as part of Long-term debt within ACE's Consolidated Balance Sheets. (c) Includes Pepco's capital lease obligations of $14 million and $27 million at December 31, 2018 and 2017 , respectively. Pepco Maturity December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 3.05 % - 7.90 % 2022 - 2048 $ 2,735 $ 2,535 Notes payable and other (b) 7.28 % - 8.88 % 2019 - 2022 16 35 Total long-term debt 2,751 2,570 Unamortized debt discount and premium, net 2 2 Unamortized debt issuance costs (34 ) (32 ) Long-term debt due within one year (15 ) (19 ) Long-term debt $ 2,704 $ 2,521 __________ (a) Substantially all of Pepco's assets are subject to the lien of its respective mortgage indenture. (b) Includes capital lease obligations of $14 million and $27 million at December 31, 2018 and 2017 , respectively. Lease payments of $14 million will be made in 2019 . DPL Maturity December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 1.81 % - 4.27 % 2023 - 2048 $ 1,370 $ 1,171 Unsecured Tax-Exempt Bonds 1.74 % - 5.40 % 2024 - 2031 112 112 Medium-terms notes (unsecured) 7.61 % - 7.72 % 2019 - 2027 22 26 Total long-term debt 1,504 1,309 Unamortized debt discount and premium, net 2 2 Unamortized debt issuance costs (12 ) (11 ) Long-term debt due within one year (91 ) (83 ) Long-term debt $ 1,403 $ 1,217 __________ (a) Substantially all of DPL's assets are subject to the lien of its respective mortgage indenture. ACE Maturity December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 3.38 % - 6.80 % 2021 - 2036 $ 1,137 $ 1,037 Transition bonds (b) 5.55 % 2023 59 90 Total long-term debt 1,196 1,127 Unamortized debt discount and premium, net (1 ) (1 ) Unamortized debt issuance costs (7 ) (5 ) Long-term debt due within one year (18 ) (281 ) Long-term debt $ 1,170 $ 840 __________ (a) Substantially all of ACE's assets are subject to the lien of its respective mortgage indenture. (b) Maturities of ACE's Transition Bonds outstanding at December 31, 2018 are $18 million in 2019, $20 million in 2020 and $21 million in 2021. Long-term debt maturities at Exelon, Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE in the periods 2019 through 2023 and thereafter are as follows: Year Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE 2019 $ 1,349 $ 906 $ 300 $ — $ — $ 125 $ 15 $ 91 $ 18 2020 3,528 2,108 500 — — 20 — — 20 2021 1,511 1 350 300 300 261 1 — 260 2022 3,084 1,024 — 350 250 310 310 — — 2023 850 — — 50 300 500 — 500 — Thereafter 24,979 (a) 4,720 7,243 (b) 2,609 (c) 2,050 4,420 2,425 913 898 Total $ 35,301 $ 8,759 $ 8,393 $ 3,309 $ 2,900 $ 5,636 $ 2,751 $ 1,504 $ 1,196 __________ (a) Includes $390 million due to ComEd and PECO financing trusts. (b) Includes $206 million due to ComEd financing trust. (c) Includes $184 million due to PECO financing trusts. Junior Subordinated Notes In June 2014, Exelon issued $1.15 billion of junior subordinated notes in the form of 23 million equity units at a stated amount of $50.00 per unit. Each equity unit represented an undivided beneficial ownership interest in Exelon’s $1.15 billion of 2.50% junior subordinated notes due in 2024 (“2024 notes”) and a forward equity purchase contract. As contemplated in the June 2014 equity unit structure, in April 2017, Exelon completed the remarketing of the 2024 notes into $1.15 billion of 3.497% junior subordinated notes due in 2022 (“Remarketing”). Exelon conducted the Remarketing on behalf of the holders of equity units and did not directly receive any proceeds therefrom. Instead, the former holders of the 2024 notes used debt remarketing proceeds towards settling the forward equity purchase contract with Exelon on June 1, 2017. Exelon issued approximately 33 million shares of common stock from treasury stock and received $1.15 billion upon settlement of the forward equity purchase contract. When reissuing treasury stock Exelon uses the average price paid to repurchase shares to calculate a gain or loss on issuance and records gains or losses directly to retained earnings. A loss on reissuance of treasury shares of $1.05 billion was recorded to retained earnings as of December 31, 2017. See Note 20 — Earnings Per Share for additional information on the issuance of common stock. Nonrecourse Debt Exelon and Generation have issued nonrecourse debt financing, in which approximately $2.9 billion of generating assets have been pledged as collateral at December 31, 2018 . Borrowings under these agreements are secured by the assets and equity of each respective project. The lenders do not have recourse against Exelon or Generation in the event of a default. If a specific project financing entity does not maintain compliance with its specific nonrecourse debt financing covenants, there could be a requirement to accelerate repayment of the associated debt or other borrowings earlier than the stated maturity dates. In these instances, if such repayment was not satisfied, the lenders or security holders would generally have rights to foreclose against the project-specific assets and related collateral. The potential requirement to satisfy its associated debt or other borrowings earlier than otherwise anticipated could lead to impairments due to a higher likelihood of disposing of the respective project-specific assets significantly before the end of their useful lives. Denver Airport. In June 2011, Generation entered into a 20-year, $7 million solar loan agreement to finance a solar construction project in Denver, Colorado. The agreement is scheduled to mature on June 30, 2031. The agreement bears interest at a fixed rate of 5.50% annually with interest payable annually. As of December 31, 2018 , $ 6 million was outstanding. CEU Upstream. In July 2011, CEU Holdings, LLC, a wholly owned subsidiary of Generation, entered into a 5-year reserve based lending agreement (RBL) associated with certain Upstream oil and gas properties. The lenders do not have recourse against Exelon or Generation in the event of default pursuant to the RBL. Borrowings under this arrangement are secured by the assets and equity of CEU Holdings. In December 2016, substantially all of the Upstream natural gas and oil exploration and production assets were sold for $37 million . The proceeds were used to reduce the debt balance by $31 million . The remaining proceeds of $6 million were being held in escrow. In addition, during 2016, $15 million of the debt was repaid using CEU Holding’s cash, resulting in an outstanding debt balance of $22 million at December 31, 2016. During 2017, additional assets were sold for $1 million and the remaining $6 million in escrow was released and applied to the debt balance resulting in an outstanding amount of $15 million at December 31, 2017. Upon final resolution, CEU Holdings will be released of its obligations regardless of the amount of asset sale proceeds received. The ultimate resolution of this matter has no direct effect on any Exelon or Generation credit facilities or other debt of an Exelon entity. At December 31, 2018 , the outstanding debt balance of $15 million was classified within Long term debt due within one year in Exelon’s and Generation’s Consolidated Balance Sheets. See Note 5 — Mergers, Acquisitions and Dispositions and Note 7 — Impairment of Long-Lived Assets and Intangibles for additional information. Holyoke Solar Cooperative. In October 2011, Generation entered into a 20-year, $11 million solar loan agreement related to a solar construction project in Holyoke, Massachusetts. The agreement is scheduled to mature on December 2031. The agreement bears interest at a fixed rate of 5.25% annually with interest payable monthly. As of December 31, 2018 , $8 million was outstanding. Antelope Valley Solar Ranch One. In December 2011, the DOE Loan Programs Office issued a guarantee for up to $646 million for a nonrecourse loan from the Federal Financing Bank to support the financing of the construction of the Antelope Valley facility. The project became fully operational in 2014. The loan will mature on January 5, 2037. Interest rates on the loan were fixed upon each advance at a spread of 37.5 basis points above U.S. Treasuries of comparable maturity. The advances were completed as of December 31, 2015 and the outstanding loan balance will bear interest at an average blended interest rate of 2.82% . As of December 31, 2018 , $508 million was outstanding. In addition, Generation has issued letters of credit to support its equity investment in the project. As of December 31, 2018 , Generation had $38 million in letters of credit outstanding related to the project. In 2017, Generation’s interests in Antelope Valley were also contributed to and are pledged as collateral for the EGR IV financing structure referenced below. Continental Wind. In September 2013, Continental Wind, LLC (Continental Wind), an indirect subsidiary of Exelon and Generation, completed the issuance and sale of $613 million senior secured notes. Continental Wind owns and operates a portfolio of wind farms in Idaho, Kansas, Michigan, Oregon, New Mexico and Texas with a total net capacity of 667 MW. The net proceeds were distributed to Generation for its general business purposes. The notes are scheduled to mature on February 28, 2033. The notes bear interest at a fixed rate of 6.00% with interest payable semi-annually. As of December 31, 2018 , $479 million was outstanding. In addition, Continental Wind entered into a $131 million letter of credit facility and $10 million working capital revolver facility. Continental Wind has issued letters of credit to satisfy certain of its credit support and security obligations. As of December 31, 2018 , the Continental Wind letter of credit facility had $114 million in letters of credit outstanding related to the project. In 2017, Generation’s interests in Continental Wind were contributed to EGRP. Refer to Note 2 - Variable Interest Entities for additional information on EGRP. ExGen Texas Power. In September 2014, EGTP, an indirect subsidiary of Exelon and Generation, issued $675 million aggregate principal amount of a nonrecourse senior secured term loan. The net proceeds were distributed to Generation for general business purposes. The loan was scheduled to mature on September 18, 2021. In addition to the financing, EGTP entered into various interest rate swaps with an initial notional amount of approximately $505 million at an interest rate of 2.34% to hedge a portion of the interest rate exposure in connection with this financing, as required by the debt covenants. On May 2, 2017, as a result of the negative impacts of certain market conditions and the seasonality of its cash flows, EGTP entered into a consent agreement with its lenders, which permitted EGTP to draw on its revolving credit facility and initiate an orderly sales process of its assets. On November 7, 2017, the debtors filed voluntary petitions for relief under Chapter 11 of Title 11 of the United States Code in the United States Bankruptcy Court for the District of Delaware. As a result, Exelon and Generation deconsolidated the nonrecourse senior secured term loan, the revolving credit facility, and the interest rate swaps from their consolidated financial stat |
Income Taxes (All Registrants)
Income Taxes (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Income Tax Disclosure [Abstract] | |
Income Taxes (All Registrants) | Income Taxes (All Registrants) Corporate Tax Reform (All Registrants) On December 22, 2017, President Trump signed the TCJA into law. The TCJA makes many significant changes to the Internal Revenue Code, including, but not limited to, (1) reducing the U.S. federal corporate tax rate from 35% to 21% ; (2) creating a 30% limitation on deductible interest expense (not applicable to regulated utilities); (3) allowing 100% expensing for the cost of qualified property (not applicable to regulated utilities); (4) eliminating the domestic production activities deduction; (5) eliminating the corporate alternative minimum tax and changing how existing alternative minimum tax credits can be realized; and (6) changing rules related to uses and limitations of net operating loss carryforwards created in tax years beginning after December 31, 2017. The most significant change that impacts the Registrants is the reduction of the corporate federal income tax rate from 35% to 21% beginning January 1, 2018. Pursuant to the enactment of the TCJA, the Registrants remeasured their existing deferred income tax balances as of December 31, 2017 to reflect the decrease in the corporate income tax rate from 35% to 21% , which resulted in a material decrease to their net deferred income tax liability balances as shown in the table below. Generation recorded a corresponding net decrease to income tax expense, while the Utility Registrants recorded corresponding regulatory liabilities or assets to the extent such amounts are probable of settlement or recovery through customer rates and an adjustment to income tax expense for all other amounts. The amount and timing of potential settlements of the established net regulatory liabilities are determined by the Utility Registrants’ respective rate regulators, subject to certain IRS “normalization” rules. See Note 4 — Regulatory Matters for additional information regarding settlements for passing back of TCJA income tax savings benefits to customers. The Registrants assessed the applicable provisions in the TCJA and recorded the associated impacts as of December 31, 2017. The Registrants recorded provisional income tax amounts as of December 31, 2017, as allowed under SAB 118 issued by the SEC in December 2017, for changes pursuant to the TCJA related to depreciation because the impacts could not be finalized upon issuance of the Registrants’ financial statements, but for which reasonable estimates could be determined. On August 3, 2018, the U.S. Department of Treasury, in conjunction with the IRS, released proposed regulations clarifying the immediate expensing provisions enacted by the TCJA, specifically that regulated utility property acquired after September 27, 2017, and placed in service by December 31, 2017, qualifies for 100% expensing. Until the proposed regulations are finalized, taxpayers may rely on the proposed regulations for tax years ending after September 28, 2017. The Registrants recorded the impact of these proposed regulations and the adjustment was immaterial. While the Registrants have recorded the impacts of the TCJA based on their interpretation of the provisions as enacted, it is expected the U.S. Department of Treasury and the IRS will issue additional interpretative guidance in the future that could result in changes to previously finalized provisions. At this time, many of the states in which Exelon does business have issued guidance regarding TCJA and the impact was not material. The one-time impacts recorded by the Registrants to remeasure their deferred income tax balances at the 21% corporate federal income tax rate as of December 31, 2017 are presented below: Successor Exelon (b) Generation ComEd PECO BGE PHI Pepco DPL ACE Net Decrease to Deferred Income Tax Liability Balances $8,624 $1,895 $2,819 $1,407 $1,120 $1,944 $968 $540 $456 Successor Exelon Generation ComEd PECO (c) BGE PHI Pepco DPL ACE Net Regulatory Liability Recorded (a) $7,315 N/A $2,818 $1,394 $1,124 $1,979 $976 $545 $458 Successor Exelon (b) Generation ComEd PECO BGE PHI Pepco DPL ACE Net Deferred Income Tax Benefit/(Expense) Recorded $1,309 $1,895 $1 $13 $(4) $(35) $(8) $(5) $(2) __________ (a) Reflects the net regulatory liabilities recorded on a pre-tax basis before taking into consideration the income tax benefits associated with the ultimate settlement with customers. (b) Amounts do not sum across due to deferred tax adjustments recorded at the Exelon Corporation parent company, primarily related to certain employee compensation plans. (c) Given the regulatory treatment of income tax benefits related to electric and gas distribution repairs, PECO remained in an overall net regulatory asset position as of December 31, 2017 after recording the impacts related to the TCJA. The net regulatory liabilities above include (1) amounts subject to IRS “normalization” rules that are required to be passed back to customers generally over the remaining useful life of the underlying assets giving rise to the associated deferred income taxes, and (2) amounts for which the timing of settlement with customers is subject to determinations by the rate regulators. The table below sets forth the Registrants’ estimated categorization of their net regulatory liabilities as of December 31, 2017. The amounts in the table below are shown on an after-tax basis reflecting future net cash outflows after taking into consideration the income tax benefits associated with the ultimate settlement with customers. Successor Exelon ComEd PECO (a) BGE PHI PEPCO DPL ACE Subject to IRS Normalization Rules $3,040 $1,400 $533 $459 $648 $299 $195 $153 Subject to Rate Regulator Determination 1,694 573 43 324 754 391 194 170 Net Regulatory Liabilities $4,734 $1,973 $576 $783 $1,402 $690 $389 $ 323 _________ (a) Given the regulatory treatment of income tax benefits related to electric and gas distribution repairs, PECO was in an overall net regulatory asset position as of December 31, 2017 after recording the impacts related to the TCJA. As a result, the amount of customer benefits resulting from the TCJA subject to the discretion of PECO's rate regulators are lower relative to the other Utility Registrants. The net regulatory liability amounts subject to the IRS normalization rules generally relate to property, plant and equipment with remaining useful lives ranging from 30 to 40 years across the Utility Registrants. For the other amounts, rate regulators could require the passing back of amounts to customers over shorter time frames. See Note 4 - Regulatory Matters for additional information. Components of Income Tax Expense or Benefit Income tax expense (benefit) from continuing operations is comprised of the following components: For the Year Ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Included in operations: Federal Current $ 226 $ 337 $ (63 ) $ 11 $ (5 ) $ (4 ) $ 28 $ (3 ) $ (14 ) Deferred (98 ) (347 ) 145 10 47 24 (21 ) 13 18 Investment tax credit amortization (24 ) (21 ) (2 ) — — (1 ) — — — State Current (1 ) 6 (29 ) 1 — 7 — — — Deferred 17 (83 ) 117 (16 ) 32 9 6 12 8 Total $ 120 $ (108 ) $ 168 $ 6 $ 74 $ 35 $ 13 $ 22 $ 12 For the Year Ended December 31, 2017 (a) Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Included in operations: Federal Current $ 194 $ 584 $ (191 ) $ 71 $ 74 $ (60 ) $ (20 ) $ (24 ) $ (12 ) Deferred (471 ) (2,005 ) 523 28 101 250 114 82 34 Investment tax credit amortization (25 ) (21 ) (2 ) — (1 ) (1 ) — — — State Current 14 65 (49 ) 14 (5 ) (4 ) (2 ) — — Deferred 162 1 136 (9 ) 49 32 13 13 4 Total $ (126 ) $ (1,376 ) $ 417 $ 104 $ 218 $ 217 $ 105 $ 71 $ 26 Successor Predecessor For the Year Ended December 31, 2016 (a) March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Included in operations: Federal Current $ 60 $ 513 $ (135 ) $ 63 $ 51 $ (118 ) $ (88 ) $ (26 ) $ (281 ) $ — Deferred 600 (254 ) 379 72 88 136 97 22 283 10 Investment tax credit amortization (24 ) (20 ) (2 ) — (1 ) — — — (1 ) — State Current 39 45 (4 ) 9 5 7 1 — (11 ) — Deferred 78 (2 ) 63 5 31 16 12 — 13 7 Total $ 753 $ 282 $ 301 $ 149 $ 174 $ 41 $ 22 $ (4 ) $ 3 $ 17 __________ (a) Exelon retrospectively adopted the new standard Revenue from Contracts with Customers. The standard was adopted as of January 1, 2018. Components of income tax expense or benefit are recast to reflect the impact of the new standard. Rate Reconciliation The effective income tax rate from continuing operations varies from the U.S. federal statutory rate principally due to the following: For the Year Ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State income taxes, net of Federal income tax benefit 0.6 (16.6 ) 8.3 (2.6 ) 6.6 3.0 2.2 6.7 7.4 Qualified NDT fund income (1.9 ) (11.8 ) — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (1.2 ) (6.5 ) (0.2 ) (0.1 ) (0.1 ) (0.2 ) (0.1 ) (0.3 ) (0.4 ) Plant basis differences (3.5 ) — (0.2 ) (14.1 ) (1.3 ) (1.6 ) (2.7 ) (0.3 ) (0.5 ) Production tax credits and other credits (2.2 ) (13.5 ) — — — — — — — Noncontrolling interests (1.0 ) (6.1 ) — — — — — — — Excess deferred tax amortization (8.3 ) — (9.1 ) (3.2 ) (8.0 ) (14.5 ) (14.8 ) (12.0 ) (14.9 ) Tax Cuts and Jobs Act of 2017 0.9 2.7 (0.1 ) — — 0.1 — — — Other 1.0 1.3 0.5 0.3 0.9 0.3 0.2 0.4 1.2 Effective income tax rate 5.4 % (29.5 )% 20.2 % 1.3 % 19.1 % 8.1 % 5.8 % 15.5 % 13.8 % For the Year Ended December 31, 2017 (a) Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % Increase (decrease) due to: State income taxes, net of Federal income tax benefit 2.3 2.9 5.7 0.6 5.4 4.8 3.2 5.4 5.6 Qualified NDT fund income 3.8 9.9 — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (0.9 ) (2.1 ) (0.2 ) (0.1 ) (0.1 ) (0.2 ) (0.1 ) (0.2 ) (0.4 ) Plant basis differences (b) (1.7 ) — 0.3 (13.8 ) 0.1 1.1 (0.4 ) 2.0 3.6 Production tax credits and other credits (1.8 ) (4.7 ) — — — — — — — Like-kind exchange (1.2 ) — 1.3 — — — — — — Merger expenses (3.6 ) (1.2 ) — — — (9.5 ) (6.3 ) (7.8 ) (19.8 ) FitzPatrick bargain purchase gain (2.2 ) (5.6 ) — — — — — — — Tax Cuts and Jobs Act of 2017 (c) (33.1 ) (128.3 ) 0.1 (2.3 ) 0.9 6.4 2.7 2.5 1.6 Other 0.1 (0.5 ) 0.2 (0.1 ) 0.2 (0.1 ) (0.2 ) 0.1 (0.4 ) Effective income tax rate (3.3 )% (94.6 )% 42.4 % 19.3 % 41.5 % 37.5 % 33.9 % 37.0 % 25.2 % Successor Predecessor For the Year Ended December 31, 2016 (a) March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL (d) ACE (d) PHI (d) PHI U.S. Federal statutory rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % Increase (decrease) due to: State income taxes, net of Federal income tax benefit (e) 3.3 3.2 5.6 1.3 5.0 15.7 52.7 6.2 5.8 11.9 Qualified NDT fund income 3.4 7.9 — — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (1.2 ) (2.3 ) (0.3 ) (0.1 ) (0.1 ) (0.2 ) (3.7 ) 0.8 1.4 (0.9 ) Plant basis differences (4.9 ) — (0.6 ) (9.6 ) (2.7 ) (22.8 ) (25.5 ) 10.3 39.0 (13.5 ) Production tax credits and other credits (3.6 ) (8.3 ) — — — — — — — — Noncontrolling interests (0.2 ) (0.6 ) — — — — — — — — Statute of limitations expiration (0.4 ) (1.7 ) — — — — — — — — Penalties 1.9 — 4.5 — — — — — (0.7 ) — Merger Expenses 5.6 1.1 — — — 23.5 112.9 (44.9 ) (89.0 ) 11.1 Other (f) (0.7 ) (1.4 ) 0.1 (1.2 ) — (1.8 ) (2.2 ) 1.3 3.3 3.6 Effective income tax rate 38.2 % 32.9 % 44.3 % 25.4 % 37.2 % 49.4 % 169.2 % 8.7 % (5.2 )% 47.2 % __________ (a) Exelon retrospectively adopted the new standard Revenue from Contracts with Customers. The standard was adopted as of January 1, 2018. The effective income tax rates are recast to reflect the impact of the new standard. (b) Includes the charges related to the transmission-related income tax regulatory asset for Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE of $ 35 million , $ 3 million , $ 5 million , $ 27 million , $ 14 million , $ 6 million and $ 7 million , respectively. See Note 4 - Regulatory Matters for additional information. (c) Included are impacts for TCJA other than the corporate rate change, including revisions further limiting tax deductions for compensation of certain highest paid executives, the write-off of foreign tax credit carryforwards, and loss of a 2015 domestic production activities deduction due to an NOL carryback. (d) DPL and ACE recognized a loss before income taxes for the year ended December 31, 2016, and PHI recognized a loss before income taxes for the period of March 24, 2016, through December 31, 2016. As a result, positive percentages represent an income tax benefit for the periods presented. (e) Includes a remeasurement of uncertain state income tax positions for Pepco and DPL. (f) At PECO, includes a cumulative adjustment related to an anticipated gas repairs tax return accounting method change. The method change request was filed and accepted in 2017. No change to the results recorded as of December 31, 2016. Tax Differences and Carryforwards The tax effects of temporary differences and carryforwards, which give rise to significant portions of the deferred tax assets (liabilities), as of December 31, 2018 and 2017 are presented below: As of December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Plant basis differences $ (12,533 ) $ (2,495 ) $ (4,059 ) $ (1,862 ) $ (1,399 ) $ (2,577 ) $ (1,148 ) $ (743 ) $ (645 ) Accrual based contracts 117 (44 ) — — — 161 — — — Derivatives and other financial instruments 89 35 69 — — 3 — — — Deferred pension and postretirement obligation 1,435 (188 ) (255 ) (26 ) (26 ) (102 ) (78 ) (46 ) (14 ) Nuclear decommissioning activities (351 ) (351 ) — — — — — — — Deferred debt refinancing costs 234 23 (7 ) — (3 ) 187 (4 ) (2 ) (1 ) Regulatory assets and liabilities (749 ) — 300 (129 ) 172 (90 ) 58 96 83 Tax loss carryforward 237 78 — 18 25 96 12 52 26 Tax credit carryforward 811 816 — — — — — — — Investment in partnerships (797 ) (775 ) — — — — — — — Other, net 934 239 151 67 12 196 98 17 19 Deferred income tax liabilities (net) $ (10,573 ) $ (2,662 ) $ (3,801 ) $ (1,932 ) $ (1,219 ) $ (2,126 ) $ (1,062 ) $ (626 ) $ (532 ) Unamortized investment tax credits (724 ) (700 ) (12 ) (1 ) (3 ) (8 ) (2 ) (2 ) (3 ) Total deferred income tax liabilities (net) and unamortized investment tax credits $ (11,297 ) $ (3,362 ) $ (3,813 ) $ (1,933 ) $ (1,222 ) $ (2,134 ) $ (1,064 ) $ (628 ) $ (535 ) As of December 31, 2017 (a) Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Plant basis differences $ (12,490 ) $ (2,819 ) $ (3,825 ) $ (1,762 ) $ (1,368 ) $ (2,521 ) $ (1,152 ) $ (717 ) $ (607 ) Accrual based contracts 150 (66 ) — — — 216 — — — Derivatives and other financial instruments (85 ) (66 ) (2 ) — — 3 — — — Deferred pension and postretirement obligation 1,463 (205 ) (285 ) (15 ) (29 ) (130 ) (78 ) (51 ) (18 ) Nuclear decommissioning activities (553 ) (553 ) — — — — — — — Deferred debt refinancing costs 217 26 (8 ) (1 ) (3 ) 203 (4 ) (2 ) (1 ) Regulatory assets and liabilities (688 ) — 489 (90 ) 136 (184 ) 39 88 86 Tax loss carryforward 344 76 33 9 11 156 40 68 35 Tax credit carryforward 861 868 1 — — 6 — — — Investment in partnerships (434 ) (416 ) — — — — — — — Other, net 746 78 141 71 13 193 94 14 16 Deferred income tax liabilities (net) $ (10,469 ) $ (3,077 ) $ (3,456 ) $ (1,788 ) $ (1,240 ) $ (2,058 ) $ (1,061 ) $ (600 ) $ (489 ) Unamortized investment tax credits (732 ) (705 ) (13 ) (1 ) (4 ) (8 ) (2 ) (3 ) (4 ) Total deferred income tax liabilities (net) and unamortized investment tax credits $ (11,201 ) $ (3,782 ) $ (3,469 ) $ (1,789 ) $ (1,244 ) $ (2,066 ) $ (1,063 ) $ (603 ) $ (493 ) __________ (a) Includes remeasurement impacts related to the TCJA. The following table provides the Registrants’ carryforwards and any corresponding valuation allowances as of December 31, 2018 : Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Federal Federal general business credits carryforwards 811 (a) 816 — — — — — — — State State net operating losses 4,103 (b) 1,544 (b) — 224 (c) 395 (d) 1,492 (e) 192 (f) 772 (g) 365 (h) Deferred taxes on state tax attributes (net) 272 104 — 18 26 102 12 52 26 Valuation allowance on state tax attributes 35 26 — — 1 6 — — — __________ (a) Exelon’s federal general business credit carryforwards will begin expiring in 2033. (b) Exelon’s and Generation's state net operating losses and credit carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2019. (c) PECO's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2031. (d) BGE's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2026. (e) PHI's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2036. (f) Pepco's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2033. (g) DPL's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2030. (h) ACE's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2031. Tabular Reconciliation of Unrecognized Tax Benefits The following tables provide a reconciliation of the Registrants’ unrecognized tax benefits as of December 31, 2018 , 2017 and 2016 : Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Unrecognized tax benefits at January 1, 2018 $ 743 $ 468 $ 2 $ — $ 120 $ 125 $ 59 $ 21 $ 14 Change to positions that only affect timing 15 15 — — — — — — — Increases based on tax positions prior to 2018 30 21 — — — 8 7 1 — Decreases based on tax positions prior to 2018 (251 ) (36 ) — — (120 ) (88 ) (66 ) (22 ) — Decrease from settlements with taxing authorities (53 ) (53 ) — — — — — — — Decreases from expiration of statute of limitations (7 ) (7 ) — — — — — — — Unrecognized tax benefits at December 31, 2018 $ 477 $ 408 $ 2 $ — $ — $ 45 $ — $ — $ 14 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Unrecognized tax benefits at January 1, 2017 $ 916 $ 490 $ (12 ) $ — $ 120 $ 172 $ 80 $ 37 $ 22 Increases based on tax positions prior to 2017 28 — 14 — — 14 — — 14 Decreases based on tax positions prior to 2017 (196 ) (17 ) — — — (61 ) (21 ) (16 ) (22 ) Decrease from settlements with taxing authorities (5 ) (5 ) — — — — — — — Unrecognized tax benefits at December 31, 2017 $ 743 $ 468 $ 2 $ — $ 120 $ 125 $ 59 $ 21 $ 14 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Unrecognized tax benefits at January 1, 2016 $ 1,078 $ 534 $ 142 $ — $ 120 $ 22 $ 8 $ 3 $ — Merger balance transfer 22 5 — — — (5 ) — — — Increases based on tax positions related to 2016 108 10 — — — 59 21 16 22 Change to positions that only affect timing (332 ) (12 ) (154 ) — — — — — — Increases based on tax positions prior to 2016 88 — — — — 96 51 18 — Decreases based on tax positions prior to 2016 (21 ) (20 ) — — — — — — — Decreases from settlements with taxing authorities (27 ) (27 ) — — — — — — — Unrecognized tax benefits at December 31, 2016 $ 916 $ 490 $ (12 ) $ — $ 120 $ 172 $ 80 $ 37 $ 22 As a result of a court decision issued in July 2018 to an unrelated taxpayer, Exelon's and Generation’s unrecognized federal and state tax benefits increased in the third quarter of 2018 by approximately $71 million . Approximately $20 million of this increase impacted Exelon's and Generation’s effective tax rate and resulted in a charge to earnings in the third quarter of 2018. Exelon’s and Generation’s unrecognized federal and state tax benefits decreased in the fourth quarter of 2018 by approximately $90 million due to the settlement of a federal audit issue with IRS Appeals. The recognition of these tax benefits decreased the effective tax rate at Exelon and Generation resulting in an income tax benefit of approximately $9 million . In the fourth quarter of 2018, Exelon, Generation, BGE, PHI, Pepco, and DPL decreased their unrecognized state tax benefits by $241 million , $33 million , $120 million , $88 million , $66 million , and $22 million , respectively, due to the receipt of favorable guidance with respect to the deductibility of certain depreciable fixed assets. The recognition of these tax benefits decreased the effective tax rate at Exelon and Generation resulting in an income tax benefit of approximately $26 million . The recognition of the tax benefits related to BGE, PHI, Pepco, and DPL was offset by corresponding regulatory liabilities and that portion had no immediate impact to their effective tax rate. Exelon established a liability for an uncertain tax position associated with the tax deductibility of certain merger commitments incurred by Exelon in connection with the acquisitions of Constellation in 2012 and PHI in 2016. In the first quarter 2017, as a part of its examination of Exelon's return, the IRS National Office issued guidance concurring with Exelon's position that the merger commitments were deductible. As a result, Exelon, Generation, PHI, Pepco, DPL, and ACE decreased their liability for unrecognized tax benefits by $146 million , $19 million , $59 million , $21 million , $16 million and $22 million , respectively, in the first quarter of 2017 resulting in a benefit to Income taxes on Exelon's, Generation's, PHI's, Pepco's, DPL's, and ACE's Consolidated Statements of Operations and Comprehensive Income and corresponding decreases in their effective tax rates. Exelon reduced the liability related to the uncertain tax position associated with the like-kind exchange in the second quarter of 2017. Unrecognized tax benefits that if recognized would affect the effective tax rate Exelon, Generation, ComEd and PHI have $463 million , $408 million , $2 million and $31 million , respectively, of unrecognized tax benefits at December 31, 2018 that, if recognized, would decrease the effective tax rate. PHI has $21 million of unrecognized state tax benefits at December 31, 2018 that, if recognized, $14 million would be in the form of a net operating loss carryforward, which is expected to require a full valuation allowance based on present circumstances. PHI and ACE have $14 million of unrecognized tax benefits at December 31, 2018 that, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate. Exelon, Generation, ComEd and PHI had $523 million , $461 million , $2 million and $32 million , respectively, of unrecognized tax benefits at December 31, 2017 that, if recognized, would decrease the effective tax rate. BGE, PHI, Pepco, DPL, and ACE have $120 million , $94 million , $59 million , $21 million and $14 million of unrecognized tax benefits at December 31, 2017 that, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate. Exelon, Generation, PHI, Pepco, DPL, and ACE had $633 million , $483 million , $93 million , $21 million , $16 million , and $22 million , respectively, of unrecognized tax benefits at December 31, 2016 that, if recognized, would decrease the effective tax rate. BGE, PHI, Pepco and DPL had $120 million , $80 million , $59 million , and $21 million of unrecognized tax benefits at December 31, 2016 that, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate. Unrecognized tax benefits that if recognized would affect only the timing of tax payments There are no unrecognized tax benefits as of December 31, 2018 that affect only the timing of tax payments. Exelon and Generation had $7 million of unrecognized tax benefits at December 31, 2017 for which the ultimate tax benefit is highly certain, but for which there is uncertainty about the timing of such benefits. Exelon, Generation and ComEd had $83 million , $7 million and $(12) million of unrecognized tax benefits at December 31, 2016 for which the ultimate tax benefit is highly certain, but for which there is uncertainty about the timing of such benefits. The disallowance of such positions would not materially affect the annual effective tax rate but would accelerate the payment of cash to, or defer the receipt of the cash tax benefit from, the taxing authority to an earlier or later period respectively. Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date Like-Kind Exchange As of December 31, 2018 , Exelon and ComEd have approximately $33 million and $ 2 million , respectively, of unrecognized federal and state income tax benefits related to the like-kind exchange litigation described further below. If Exelon does not appeal the October 2018 U.S. Court of Appeals for the Seventh Circuit's decision to the U.S. Supreme Court, Exelon's and ComEd's unrecognized tax benefits will decrease in the first quarter of 2019. See below for further details. Settlement of Income Tax Audits, Refund Claims, and Litigation As of December 31, 2018 , Exelon, Generation, PHI and ACE have approximately $425 million , $411 million , $14 million , and $ 14 million respectively, of unrecognized federal and state tax benefits that could significantly decrease within the 12 months after the reporting date as a result of completing audits, potential settlements, refund claims, and the outcomes of pending court cases. Of the above unrecognized tax benefits, Exelon and Generation have $411 million that, if recognized, would decrease the effective tax rate. The unrecognized tax benefit related to PHI and ACE, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate. Total amounts of interest and penalties recognized The following tables represent the net interest and penalties receivable (payable), including interest and penalties related to tax positions reflected in the Registrants’ Consolidated Balance Sheets. Net interest receivable (payable) as of Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE December 31, 2018 $ 236 $ (2 ) $ 4 $ — $ — $ 1 $ — $ — $ — December 31, 2017 233 (3 ) 4 — — 2 — — — Net penalties payable as of Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE December 31, 2018 $ (17 ) $ — $ — $ — $ — $ — $ — $ — $ — December 31, 2017 (17 ) — — — — — — — — The following tables set forth the net interest and penalty expense, including interest and penalties related to tax positions, recognized in Interest expense, net and Other, net in Other income and deductions in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. Net interest expense (income) for the years ended Exelon Generation ComEd PECO BGE Pepco DPL ACE December 31, 2018 $ (3 ) $ — $ — $ — $ — $ — $ — $ — December 31, 2017 37 (1 ) 11 — — — — — December 31, 2016 165 (13 ) 117 — — 6 — (1 ) Net penalty expense (income) for the years ended Exelon Generation ComEd PECO BGE Pepco DPL ACE December 31, 2018 $ — $ — $ — $ — $ — $ — $ — $ — December 31, 2017 (2 ) — — — — — — — December 31, 2016 106 — 86 — — — — — Successor Predecessor PHI December 31, 2018 December 31, 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Net interest expense $ — $ — $ (2 ) $ — Description of tax years open to assessment by major jurisdiction Taxpayer Open Years Exelon (and predecessors) and subsidiaries consolidated federal income tax returns 1999, 2001-2017 PHI Holdings and subsidiaries consolidated federal income tax returns 2013, 2015-2016 Exelon and subsidiaries Illinois unitary income tax returns 2010-2017 Constellation combined New York corporate income tax returns 2010-March 2012 Exelon combined New York corporate income tax returns 2011-2017 Exelon New Jersey corporate income tax returns 2013-2017 Exelon Pennsylvania corporate net income tax returns 2011-2017 PECO Pennsylvania separate company returns 2015-2017 DPL Delaware separate company returns Same as federal ACE New Jersey separate company returns 2014-2017 Exelon and subsidiaries District of Columbia corporate income tax returns 2015-2017 PHI Holdings and subsidiaries District of Columbia corporate income tax returns 2015-2016 Various separate company Maryland corporate net income tax returns Same as federal Other Tax Matters Like-Kind Exchange Exelon, through its ComEd subsidiary, took a position on its 1999 income tax return to defer approximately $1.2 billion of tax gain on the sale of ComEd’s fossil generating assets. The gain was deferred by reinvesting a portion of the proceeds from the sale in qualifying replacement property under the like-kind exchange provisions of the IRC. The like-kind exchange replacement property purchased by Exelon included interests in three municipal-owned electric generation facilities which were properly leased back to the municipalities. As previously disclosed, Exelon terminated its investment in one of the leases in 2014 and the remaining two leases were terminated in 2016. The IRS asserted that the Exelon purchase and leaseback transaction was substantially similar to a leasing transaction, known as a SILO, which is a listed transaction that the IRS has identified as a potentially abusive tax shelter. Thus, they disagreed with Exelon's position and asserted that the entire gain of approximately $1.2 billion was taxable in 1999. In 2013, the IRS issued a notice of deficiency to Exelon and Exelon filed a petition to initiate litigation in the United States Tax Court. In 2016, the Tax Court held that Exelon was not entitled to defer gain on the transaction. In addition to the tax and interest related to the gain deferral, the Tax Court also ruled that Exelon was liable for $90 million in penalties and interest on the penalties. Exelon has fully paid the amounts assessed resulting from the Tax Court decision. In September 2017, Exelon appealed the Tax Court decision to the U.S. Court of Appeals for the Seventh Circuit. In October 2018, the U.S. Court of Appeals for the Seventh Circuit affirmed the Tax Court’s decision. Exelon filed a petition seeking rehearing of the Seventh Circuit’s decision, but the Seventh Circuit denied that petition in December 2018. Exelon has until March 5, 2019 to seek a further review by the U.S. Supreme Court. State Income Tax Law Changes On April 24, 2018, Maryland enacted companion bills, House Bill 1794 and Senate Bill 1090, providing for a phase in of a single sales factor apportionment formula from the current three factor formula for determining an entity's Maryland state income taxes. The single sales factor will be fully phased in by 2022. In the second quarter of 2018, Exelon, Generation, PHI, Pepco and DPL recorded a one-time increase to deferred income taxes of approximately $16 million , $5 million , $17 million , $16 million and $1 million , respectively. At PHI, Pepco and DPL, the increase to the Maryland deferred income tax liability was offset by regulatory assets. Further, the change in tax law is not expected to have a material ongoing impact to Exelon's, Generation's, PHI's, Pepco's or DPL's future results of operations. Long-Term Marginal State Income Tax Rate (Exelon, Generation, PHI and Pepco) In the third quarter of 2018, Exelon reviewed and updated its marginal state income tax rates based on 2017 state apportionment rates. As a result of the rate changes, in the third quarter of 2018, Exelon, Generation, PHI and DPL recorded a one-time decrease to deferred income taxes of approximately $50 million , $53 million , $4 million and $2 million respectively. Pepco recorded a one-time increase to deferred income taxes of approximately $1 million . Exelon, PHI and DPL recorded a corresponding regulatory liability of approximately $1 million , $1 million and $2 million respectively. Pepco recorded a corresponding regulatory asset of approximately $1 million . Further, Exelon, Generation and PHI recorded a decrease to income tax expense (net of federal taxes) of approximately $50 million , $53 million and $3 million . Allocation of Tax Benefits (All Registrants) Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE are all party to an agreement with Exelon and other subsidiaries of Exelon that provides for the allocation of consolidated tax liabilities and benefits (Tax Sharing Agreement). The Tax Sharing Agreement provides that each party is allo |
Asset Retirement Obligations (A
Asset Retirement Obligations (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Asset Retirement Obligation Disclosure [Abstract] | |
Asset Retirement Obligations (All Registrants) | Asset Retirement Obligations (All Registrants) Nuclear Decommissioning Asset Retirement Obligations Generation has a legal obligation to decommission its nuclear power plants following the expiration of their operating licenses. To estimate its decommissioning obligation related to its nuclear generating stations for financial accounting and reporting purposes, Generation uses a probability-weighted, discounted cash flow model which, on a unit-by-unit basis, considers multiple outcome scenarios that include significant estimates and assumptions, and are based on decommissioning cost studies, cost escalation rates, probabilistic cash flow models and discount rates. Generation updates its ARO annually unless circumstances warrant more frequent updates, based on its review of updated cost studies and its annual evaluation of cost escalation factors and probabilities assigned to various scenarios. The following table provides a rollforward of the nuclear decommissioning ARO reflected in Exelon’s and Generation’s Consolidated Balance Sheets, from January 1, 2017 to December 31, 2018 : Nuclear decommissioning ARO at January 1, 2017 $ 8,734 Accretion expense 458 Acquisition of FitzPatrick 444 Net increase due to changes in, and timing of, estimated future cash flows 34 Costs incurred related to decommissioning plants (8 ) Nuclear decommissioning ARO at December 31, 2017 (a) 9,662 Accretion expense 478 Net decrease due to changes in, and timing of, estimated future cash flows (77 ) Costs incurred related to decommissioning plants (58 ) Nuclear decommissioning ARO at December 31, 2018 (a) (b) $ 10,005 __________ (a) Includes $22 million and $13 million as the current portion of the ARO at December 31, 2018 and 2017 , respectively, which is included in Other current liabilities in Exelon’s and Generation’s Consolidated Balance Sheets. (b) Includes $772 million of ARO related to Oyster Creek which is classified as Liabilities held for sale in Exelon's and Generation's Consolidated Balance Sheets at December 31, 2018 . See Note 5 — Mergers, Acquisitions and Dispositions for additional information. The net $77 million decrease in the ARO during 2018 for changes in the amounts and timing of estimated decommissioning cash flows was driven by multiple adjustments throughout the year, some with offsetting impacts. These adjustments include a $203 million decrease primarily due to lower estimated costs for the construction of interim spent fuel storage at TMI and a net decrease in estimated costs to decommission Calvert Cliffs, FitzPatrick, Limerick, and Salem nuclear units resulting from the completion of updated cost studies. These adjustments also include a decrease due to changes in decommissioning scenarios and their probabilities. These decreases were partially offset by a $116 million increase for the impact of the early retirement and the announced pending sale of Oyster Creek and a $122 million increase for estimated cost escalation rates, primarily for labor, energy and waste burial costs. See Note 5 — Mergers, Acquisitions and Dispositions and Note 8 — Early Plant Retirements for additional information regarding Oyster Creek. The net $34 million increase in the ARO during 2017 for changes in the amounts and timing of estimated decommissioning cash flows was driven by multiple adjustments throughout the year, some with offsetting impacts. These adjustments include a $178 million increase due to higher assumed probabilities of early retirement of Salem and a $138 million increase in TMI’s ARO liability associated with the May 30, 2017 announcement to early retire the unit on September 30, 2019. The increase in TMI's ARO liability incorporates the early shutdown date, increases in the probabilities of longer term decommissioning scenarios, and an increase in the estimated costs to decommission based on an updated decommissioning cost study. See Note 8 — Early Plant Retirements for additional information regarding Salem and TMI. These increases in the ARO were partially offset by a $180 million decrease for refinements in estimated fleet wide labor costs expected to be incurred for certain on-site personnel during decommissioning as well as net decreases resulting from updates to the cost studies of Clinton, Quad Cities and Dresden. NDT Funds NDT funds have been established for each generation station unit to satisfy Generation’s nuclear decommissioning obligations. Generally, NDT funds established for a particular unit may not be used to fund the decommissioning obligations of any other unit. The NDT funds associated with Generation's nuclear units have been funded with amounts collected from the previous owners and their respective utility customers. PECO is authorized to collect funds, in revenues, for decommissioning the former PECO nuclear plants through regulated rates, and these collections are scheduled through the operating lives of the former PECO plants. The amounts collected from PECO customers are remitted to Generation and deposited into the NDT funds for the unit for which funds are collected. Every five years, PECO files a rate adjustment with the PAPUC that reflects PECO’s calculations of the estimated amount needed to decommission each of the former PECO units based on updated fund balances and estimated decommissioning costs. The rate adjustment is used to determine the amount collectible from PECO customers. On March 31, 2017, PECO filed its Nuclear Decommissioning Cost Adjustment with the PAPUC proposing an annual recovery from customers of approximately $4 million . This amount reflects a decrease from the previously approved annual collection of approximately $ 24 million primarily due to the removal of the collections for Limerick Units 1 and 2 as a result of the NRC approving the extension of the operating licenses for an additional 20 years. On August 8, 2017, the PAPUC approved the filing and the new rates became effective January 1, 2018. Any shortfall of funds necessary for decommissioning, determined for each generating station unit, is ultimately required to be funded by Generation, with the exception of a shortfall for the current decommissioning activities at Zion Station, where certain decommissioning activities have been transferred to a third-party (see Zion Station Decommissioning below) and the CENG units, where any shortfall is required to be funded by both Generation and EDF. Generation, through PECO, has recourse to collect additional amounts from PECO customers related to a shortfall of NDT funds for the former PECO units, subject to certain limitations and thresholds, as prescribed by an order from the PAPUC. Generally, PECO, and likewise Generation will not be allowed to collect amounts associated with the first $50 million of any shortfall of trust funds compared to decommissioning costs, as well as 5% of any additional shortfalls, on an aggregate basis for all former PECO units. The initial $50 million and up to 5% of any additional shortfalls would be borne by Generation. No recourse exists to collect additional amounts from utility customers for any of Generation's other nuclear units. With respect to the former ComEd and PECO units, any funds remaining in the NDTs after all decommissioning has been completed are required to be refunded to ComEd’s or PECO’s customers, subject to certain limitations that allow sharing of excess funds with Generation related to the former PECO units. With respect to Generation's other nuclear units, Generation retains any funds remaining after decommissioning. However, in connection with CENG's acquisition of the Nine Mile Point and Ginna plants and settlements with certain regulatory agencies, CENG is subject to certain conditions pertaining to NDT funds that, if met, could possibly result in obligations to make payments to certain third parties (clawbacks). For Nine Mile Point and Ginna, the clawback provisions are triggered only in the event that the required decommissioning activities are discontinued or not started or completed in a timely manner. In the event that the clawback provisions are triggered for Nine Mile Point, then, depending upon the triggering event, an amount equal to 50% of the total amount withdrawn from the funds for non-decommissioning activities or 50% of any excess funds in the trust funds above the amounts required for decommissioning (including spent fuel management and decommissioning) is to be paid to the Nine Mile Point sellers. In the event that the clawback provisions are triggered for Ginna, then an amount equal to any estimated cost savings realized by not completing any of the required decommissioning activities is to be paid to the Ginna sellers. Generation expects to comply with applicable regulations and timely commence and complete all required decommissioning activities. At December 31, 2018 and 2017 , Exelon and Generation had NDT funds totaling $12,695 million and $ 13,349 million , respectively. Included within the December 31, 2018 balance is the $890 million reclassification of Oyster Creek NDT as Assets held for sale in Exelon's and Generation's Consolidated Balance Sheets. See Note 5 — Mergers, Acquisitions and Dispositions for additional information regarding the announced pending sale of Oyster Creek. The NDT funds include $144 million and $77 million for the current portion of the NDT at December 31, 2018 and 2017 , respectively, which are included in Other current assets in Exelon's and Generation's Consolidated Balance Sheets. See Note 11 — Fair Value of Financial Assets and Liabilities for additional information related to the NDT funds. The following table provides unrealized (losses) gains on NDT funds of Exelon and Generation for the years ended 2018 , 2017 and 2016 : 2018 2017 2016 Net unrealized (losses) gains on NDT funds—Regulatory Agreement Units (a) $ (715 ) $ 455 $ 216 Net unrealized (losses) gains on NDT funds—Non-Regulatory Agreement Units (b) (483 ) 521 194 __________ (a) Net unrealized (losses) gains related to Generation’s NDT funds associated with Regulatory Agreement Units are included in Regulatory liabilities in Exelon’s Consolidated Balance Sheets and Noncurrent payables to affiliates in Generation’s Consolidated Balance Sheets. (b) Net unrealized (losses) gains related to Generation’s NDT funds with Non-Regulatory Agreement Units are included within Other, net in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. Realized earnings, including interest and dividends on the NDT funds, for the non-Regulatory Agreement Units investments are recognized when earned and are included in Other, net in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income whereas the Regulatory Agreement Units are eliminated within Other, net. Accounting Implications of the Regulatory Agreements with ComEd and PECO Based on the regulatory agreements with the ICC and PAPUC that dictate Generation’s obligations related to the shortfall or excess of NDT funds necessary for decommissioning the former ComEd units on a unit-by-unit basis and the former PECO units in total, decommissioning-related activities, including realized and unrealized gains and losses on the NDT funds and accretion of the decommissioning obligation, are generally offset within Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. For the former ComEd units, decommissioning-related activities are generally offset within Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income as long as the NDT funds are expected to exceed the total estimated decommissioning obligation. For the former PECO units, decommissioning-related activities are generally offset within Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income regardless of whether the NDT funds are expected to exceed or fall short of the total estimated decommissioning obligation. The offset of decommissioning-related activities within the Consolidated Statement of Operations and Comprehensive Income results in an equal adjustment to the noncurrent payables to affiliates at Generation. ComEd and PECO have recorded an equal noncurrent affiliate receivable from Generation and corresponding regulatory liability. Should the expected value of the NDT fund for any former ComEd unit fall below the amount of the expected decommissioning obligation for that unit, the accounting to offset decommissioning-related activities in the Consolidated Statement of Operations and Comprehensive Income for that unit would be discontinued, the decommissioning-related activities would be recognized in the Consolidated Statements of Operations and Comprehensive Income and the adverse impact to Exelon’s and Generation’s financial statements could be material. As of December 31, 2018 , the NDT funds of each of the former ComEd units, except for Zion (see Zion Station Decommissioning below), are expected to exceed the related decommissioning obligation for each of the units. For the purposes of making this determination, the decommissioning obligation referred to is different, as described below, from the calculation used in the NRC minimum funding obligation filings based on NRC guidelines. Any changes to the PECO regulatory agreements could impact Exelon’s and Generation’s ability to offset decommissioning-related activities within the Consolidated Statement of Operations and Comprehensive Income, and the impact to Exelon’s and Generation’s financial statements could be material. The decommissioning-related activities related to the Non-Regulatory Agreement Units are reflected in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. See Note 4 — Regulatory Matters and Note 25 — Related Party Transactions for additional information regarding regulatory liabilities at ComEd and PECO and intercompany balances between Generation, ComEd and PECO reflecting the obligation to refund to customers any decommissioning-related assets in excess of the related decommissioning obligations. Zion Station Decommissioning In 2010, Generation completed an Asset Sale Agreement (ASA) under which ZionSolutions assumed responsibility for decommissioning Zion Station and Generation transferred to ZionSolutions substantially all the Zion Station’s assets, including the related NDT funds. Pursuant to the ASA, ZionSolutions will periodically request reimbursement, subject to certain restrictions, from the Zion Station-related NDT funds for costs incurred related to its decommissioning efforts at Zion Station. As the transfer of the Zion Station assets did not qualify for asset sale accounting treatment, the related NDT funds were reclassified as pledged assets for Zion Station decommissioning, which are recorded within Other current assets within Generation’s and Exelon’s Consolidated Balance Sheets and will continue to be measured in the same manner as prior to the completion of the transaction, and the transferred ARO for decommissioning was replaced with a payable for Zion Station decommissioning, which is recorded in Other current liabilities in Exelon’s and Generation’s Consolidated Balance Sheets. Changes in the value of the Zion Station NDT fund assets, net of applicable taxes, are recorded as a change in the payable to ZionSolutions. At no point will the payable to ZionSolutions exceed the project budget of the costs remaining to decommission Zion Station. Generation has retained its obligation for the SNF. Following ZionSolutions' completion of its contractual obligations and transfer of the NRC license to Generation, Generation will store the SNF at Zion Station until it is transferred to the DOE for ultimate disposal, and will complete all remaining decommissioning activities associated with the SNF dry storage facility. Generation has a liability of $120 million , which is included within the nuclear decommissioning ARO at December 31, 2018 . Generation also has retained NDT assets to fund its obligation to maintain the SNF at Zion Station until transfer to the DOE and to complete all remaining decommissioning activities for the SNF storage facility. Any shortage of funds necessary to maintain the SNF and decommission the SNF storage facility is ultimately required to be funded by Generation. Any Zion Station NDT funds remaining after the completion of all decommissioning activities will be returned to ComEd customers in accordance with the applicable orders. The following table provides Exelon's and Generation's pledged assets and payables to ZionSolutions, and withdrawals by ZionSolutions at December 31, 2018 and 2017 : 2018 2017 Carrying value of Zion Station pledged assets $ 9 $ 39 Current payable to ZionSolutions (a) 9 37 Cumulative withdrawals by ZionSolutions to pay decommissioning costs (b) 965 942 _______ (a) Included in Other current liabilities within Exelon's and Generation's Consolidated Balance Sheets. Excludes a liability recorded within Exelon’s and Generation’s Consolidated Balance Sheets related to the tax obligation on the unrealized gains and losses associated with the Zion Station NDT funds. The NDT funds will be utilized to satisfy the tax obligations as gains and losses are realized. (b) Includes project expenses to decommission Zion Station and estimated tax payments on Zion Station NDT fund earnings. ZionSolutions leased the land associated with Zion Station from Generation pursuant to a Lease Agreement. Under the Lease Agreement, ZionSolutions has committed to complete the required decommissioning work according to an established schedule and constructed a dry cask storage facility on the land and has loaded the SNF from the SNF pools onto the dry cask storage facility at Zion Station. Rent payable under the Lease Agreement is $1.00 per year, although the Lease Agreement requires ZionSolutions to pay property taxes associated with Zion Station and penalty rents may accrue if there are unexcused delays in the progress of decommissioning work at Zion Station or the construction of the dry cask SNF storage facility. To reduce the risk of default by ZionSolutions, EnergySolutions provided a $200 million letter of credit to be used to fund decommissioning costs in the event the NDT assets are insufficient. In accordance with the terms of the ASA, the letter of credit was reduced to $45 million in May 2018 due to the completion of key decommissioning milestones. EnergySolutions and its parent company have also provided a performance guarantee and EnergySolutions has entered into other agreements that will provide rights and remedies for Generation and the NRC in the case of other specified events of default, including a special purpose easement for disposal capacity at the EnergySolutions site in Clive, Utah, for all LLRW volume of Zion Station. NRC Minimum Funding Requirements NRC regulations require that licensees of nuclear generating facilities demonstrate reasonable assurance that funds will be available in specified minimum amounts to decommission the facility at the end of its life. The estimated decommissioning obligations as calculated using the NRC methodology differ from the ARO recorded in Generation’s and Exelon’s Consolidated Balance Sheets primarily due to differences in the type of costs included in the estimates, the basis for estimating such costs, and assumptions regarding the decommissioning alternatives to be used, potential license renewals, decommissioning cost escalation, and the growth rate in the NDT funds. Under NRC regulations, if the minimum funding requirements calculated under the NRC methodology are less than the future value of the NDT funds, also calculated under the NRC methodology, then the NRC requires either further funding or other financial guarantees. Key assumptions used in the minimum funding calculation using the NRC methodology at December 31, 2018 include: (1) consideration of costs only for the removal of radiological contamination at each unit; (2) the option on a unit-by-unit basis to use generic, non-site specific cost estimates; (3) consideration of only one decommissioning scenario for each unit; (4) the plants cease operation at the end of their current license lives (with no assumed license renewals for those units that have not already received renewals and with an assumed end-of-operations date of 2019 for TMI); (5) the assumption of current nominal dollar cost estimates that are neither escalated through the anticipated period of decommissioning, nor discounted using the CARFR; and (6) assumed annual after-tax returns on the NDT funds of 2% ( 3% for the former PECO units, as specified by the PAPUC). In contrast, the key criteria and assumptions used by Generation to determine the ARO and to forecast the target growth in the NDT funds at December 31, 2018 include: (1) the use of site specific cost estimates that are updated at least once every five years; (2) the inclusion in the ARO estimate of all legally unavoidable costs required to decommission the unit (e.g., radiological decommissioning and full site restoration for certain units, on-site spent fuel maintenance and storage subsequent to ceasing operations and until DOE acceptance, and disposal of certain low-level radioactive waste); (3) the consideration of multiple scenarios where decommissioning and site restoration activities, as applicable, are completed under possible scenarios ranging from 10 to 70 years after the cessation of plant operations; (4) the consideration of multiple end of life scenarios; (5) the measurement of the obligation at the present value of the future estimated costs and an annual average accretion of the ARO of approximately 5% through a period of approximately 30 years after the end of the extended lives of the units; and (6) an estimated targeted annual pre-tax return on the NDT funds of 5.0% to 6.2% (as compared to a historical 5-year annual average pre-tax return of approximately 4.9% ). Generation is required to provide to the NRC a biennial report by unit (annually for units that have been retired or are within five years of the current approved license life), based on values as of December 31, addressing Generation’s ability to meet the NRC minimum funding levels. Depending on the value of the trust funds, Generation may be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional contributions to the trusts, which could be significant, to ensure that the trusts are adequately funded and that NRC minimum funding requirements are met. As a result, Exelon’s and Generation’s cash flows and financial positions may be significantly adversely affected. Generation filed its biennial decommissioning funding status report with the NRC on March 30, 2017 for all units except for Zion Station which is included in a separate report to the NRC submitted by ZionSolutions (see Zion Station Decommissioning above) and FitzPatrick which is still owned by Entergy as of the NRC reporting period. This status report demonstrated adequate decommissioning funding assurance for all units except for Peach Bottom Unit 1. As a former PECO plant, financial assurance for decommissioning Peach Bottom Unit 1 is provided by the NDT fund in addition to collections from PECO ratepayers. See NDT Funds section above for additional information. On March 28, 2018, Generation submitted its annual decommissioning funding status report with the NRC for shutdown reactors, reactors within five years of shutdown except for Zion Station which is included in a separate report to the NRC submitted by EnergySolutions (see Zion Station Decommissioning above), and reactor involved in an acquisition. This report reflected the status of decommissioning funding assurance as of December 31, 2017 and included an update for the acquisition of FitzPatrick on March 31, 2017, the early retirement of TMI announced on May 30, 2017, an adjustment for the February 2, 2018 announced retirement date of Oyster Creek and the updated status of Peach Bottom Unit 1 based on the new collections rate described above. As of December 31, 2017, Generation provided adequate decommissioning funding assurance for all of its shutdown reactors, reactors within five years of shutdown, and reactor involved in an acquisition. Generation will file its next decommissioning funding status report for all units with the NRC by March 31, 2019. This report will reflect the status of decommissioning funding assurance as of December 31, 2018. A shortfall at any unit could necessitate that Generation address the shortfall by, among other things, obtaining a parental guarantee for Generation's share of the funding assurance. However, the amount of any guarantee or other assurance will ultimately depend on the decommissioning approach, the associated level of costs, and the decommissioning trust fund investment performance going forward. As the future values of trust funds change due to market conditions, the NRC minimum funding status of Generation’s units will change. In addition, if changes occur to the regulatory agreement with the PAPUC that currently allows amounts to be collected from PECO customers for decommissioning the former PECO units, the NRC minimum funding status of those plants could change at subsequent NRC filing dates. Non-Nuclear Asset Retirement Obligations (All Registrants) Generation has AROs for plant closure costs associated with its fossil and renewable generating facilities, including asbestos abatement, removal of certain storage tanks, restoring leased land to the condition it was in prior to construction of renewable generating stations and other decommissioning-related activities. The Utility Registrants have AROs primarily associated with the abatement and disposal of equipment and buildings contaminated with asbestos and PCBs. See Note 1 — Significant Accounting Policies for additional information on the Registrants’ accounting policy for AROs. The following table provides a rollforward of the non-nuclear AROs reflected in the Registrants’ Consolidated Balance Sheets from January 1, 2017 to December 31, 2018 : Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Non-nuclear AROs at January 1, 2017 $ 393 $ 199 $ 121 $ 28 $ 24 $ 14 $ 2 $ 9 $ 3 Net (decrease) increase due to changes in, and timing of, estimated future cash flows (11 ) (1 ) (13 ) (1 ) 2 2 1 1 — Development projects 1 1 — — — — — — — Accretion expense (a) 18 10 7 1 — — — — — Deconsolidation of EGTP (7 ) (7 ) — — — — — — — Payments (10 ) (5 ) (2 ) (1 ) (2 ) — — — — Non-nuclear AROs at December 31, 2017 384 197 113 27 24 16 3 10 3 Net increase due to changes in, and timing of, estimated future cash flows (b) 80 35 7 — 2 36 34 1 1 Accretion expense (a) 16 10 4 1 1 — — — — Asset divestitures (3 ) (3 ) — — — — — — — Payments (6 ) (1 ) (3 ) — (2 ) — — — — Non-nuclear AROs at December 31, 2018 $ 471 $ 238 $ 121 $ 28 $ 25 $ 52 $ 37 $ 11 $ 4 __________ (a) For ComEd and PECO, the majority of the accretion is recorded as an increase to a regulatory asset due to the associated regulatory treatment. (b) In 2018, Pepco recorded an increase of $22 million in Operating and maintenance expense primarily related to asbestos identified at its Buzzard Point property as part of an annual ARO study. Buzzard Point is a waterfront property in the District of Columbia occupied by an active substation and former Pepco operated steam plant building, which Pepco retired and closed in 1981. |
Retirement Benefits (All Regist
Retirement Benefits (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Retirement Benefits [Abstract] | |
Retirement Benefits (All Registrants) | (All Registrants) Exelon sponsors defined benefit pension plans and other postretirement benefit plans for essentially all current employees. Substantially all non-union employees and electing union employees hired on or after January 1, 2001 participate in cash balance pension plans. Effective January 1, 2009, substantially all newly-hired union-represented employees participate in cash balance pension plans. Effective February 1, 2018, most newly-hired Generation and BSC non-represented, non-craft, employees are not eligible for pension benefits, and will instead be eligible to receive an enhanced non-discretionary employer contribution in an Exelon defined contribution savings plan. Effective January 1, 2018, most newly-hired non-represented, non-craft, employees are not eligible for OPEB benefits and employees represented by Local 614 are not eligible for retiree health care benefits. Effective January 1, 2019, Exelon is merging the Exelon Corporation Cash Balance Pension Plan (CBPP) into the Exelon Corporation Retirement Program (ECRP). The merging of the plans is not changing the benefits offered to the plan participants and, thus, has no impact on Exelon's pension obligation. However, beginning in 2019, actuarial losses and gains related to the CBPP and ECRP will be amortized over participants’ average remaining service period of the merged ECRP rather than each individual plan. The table below shows the pension and other postretirement benefit plans in which employees of each operating company participated at December 31, 2018 : Operating Company (e) Name of Plan: Generation ComEd PECO BGE BSC PHI Pepco DPL ACE Qualified Pension Plans: Exelon Corporation Retirement Program (a) X X X X X X X Exelon Corporation Cash Balance Pension Plan (a) X X X X X X X X X Exelon Corporation Pension Plan for Bargaining Unit Employees (a) X X X Exelon New England Union Employees Pension Plan (a) X Exelon Employee Pension Plan for Clinton, TMI and Oyster Creek (a) X X X X Pension Plan of Constellation Energy Group, Inc. (b) X X X X X X X Pension Plan of Constellation Energy Nuclear Group, LLC (c) X X X X X Nine Mile Point Pension Plan (c) X X Constellation Mystic Power, LLC Union Employees Pension Plan Including Plan A and Plan B (b) X Pepco Holdings LLC Retirement Plan (d) X X X X X X X X X Non-Qualified Pension Plans: Exelon Corporation Supplemental Pension Benefit Plan and 2000 Excess Benefit Plan (a) X X X X X Exelon Corporation Supplemental Management Retirement Plan (a) X X X X X X Constellation Energy Group, Inc. Senior Executive Supplemental Plan (b) X X X Constellation Energy Group, Inc. Supplemental Pension Plan (b) X X X Constellation Energy Group, Inc. Benefits Restoration Plan (b) X X X X X Constellation Energy Nuclear Plan, LLC Executive Retirement Plan (c) X X Constellation Energy Nuclear Plan, LLC Benefits Restoration Plan (c) X X Baltimore Gas & Electric Company Executive Benefit Plan (b) X X X Baltimore Gas & Electric Company Manager Benefit Plan (b) X X X X Pepco Holdings LLC 2011 Supplemental Executive Retirement Plan (d) X X X X X Conectiv Supplemental Executive Retirement Plan (d) X X X X X Pepco Holdings LLC Combined Executive Retirement Plan (d) X X X Atlantic City Electric Director Retirement Plan (d) X Operating Company (e) Name of Plan: Generation ComEd PECO BGE BSC PHI Pepco DPL ACE Other Postretirement Benefit Plans: PECO Energy Company Retiree Medical Plan (a) X X X X X X X X X Exelon Corporation Health Care Program (a) X X X X X X X X Exelon Corporation Employees’ Life Insurance Plan (a) X X X X X Exelon Corporation Health Reimbursement Arrangement Plan (a) X X X X X Constellation Energy Group, Inc. Retiree Medical Plan (b) X X X X X Constellation Energy Group, Inc. Retiree Dental Plan (b) X X X Constellation Energy Group, Inc. Employee Life Insurance Plan and Family Life Insurance Plan (b) X X X X X Constellation Mystic Power, LLC Post-Employment Medical Account Savings Plan (b) X Exelon New England Union Post-Employment Medical Savings Account Plan (a) X Retiree Medical Plan of Constellation Energy Nuclear Group LLC (c) X X X Retiree Dental Plan of Constellation Energy Nuclear Group LLC (c) X X X Nine Mile Point Nuclear Station, LLC Medical Care and Prescription Drug Plan for Retired Employees (c) X X Pepco Holdings LLC Welfare Plan for Retirees (d) X X X X X X X X X ______________________ (a) These plans are collectively referred to as the legacy Exelon plans. (b) These plans are collectively referred to as the legacy Constellation Energy Group (CEG) Plans. (c) These plans are collectively referred to as the legacy CENG plans. (d) These plans are collectively referred to as the legacy PHI plans. (e) Employees generally remain in their legacy benefit plans when transferring between operating companies. Exelon’s traditional and cash balance pension plans are intended to be tax-qualified defined benefit plans. Exelon has elected that the trusts underlying these plans be treated as qualified trusts under the IRC. If certain conditions are met, Exelon can deduct payments made to the qualified trusts, subject to certain IRC limitations. Benefit Obligations, Plan Assets and Funded Status Exelon recognizes the overfunded or underfunded status of defined benefit pension and OPEB plans as an asset or liability on its balance sheet, with offsetting entries to AOCI and regulatory assets (liabilities), in accordance with the applicable authoritative guidance. The measurement date for the plans is December 31. During the first quarter of 2018, Exelon received an updated valuation of its pension and OPEB to reflect actual census data as of January 1, 2018. This valuation resulted in an increase to the pension and OPEB obligations of $23 million and $14 million, respectively. Additionally, accumulated other comprehensive loss decreased by $18 million (after-tax) and regulatory assets and liabilities increased by $61 million and $1 million, respectively. In connection with the acquisition of FitzPatrick in 2017, Exelon recorded pension and OPEB obligations for FitzPatrick employees of $16 million and $17 million , respectively. See Note 5 — Mergers, Acquisitions and Dispositions for additional information of the acquisition of FitzPatrick. The following tables provide a rollforward of the changes in the benefit obligations and plan assets for the most recent two years for all plans combined: Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2018 2017 Change in benefit obligation: Net benefit obligation at beginning of year $ 22,337 $ 21,060 $ 4,856 $ 4,457 Service cost 405 387 112 106 Interest cost 802 842 175 182 Plan participants’ contributions — — 45 53 Actuarial (gain) loss (a) (1,561 ) 1,182 (540 ) 350 Plan amendments (4 ) 9 — — Acquisitions (b) — 16 — 17 Settlements (48 ) (34 ) (4 ) — Gross benefits paid (1,239 ) (1,125 ) (275 ) (309 ) Net benefit obligation at end of year $ 20,692 $ 22,337 $ 4,369 $ 4,856 Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2018 2017 Change in plan assets: Fair value of net plan assets at beginning of year $ 18,573 $ 16,791 $ 2,732 $ 2,578 Actual return on plan assets (945 ) 2,600 (136 ) 346 Employer contributions 337 341 46 64 Plan participants’ contributions — — 45 53 Gross benefits paid (1,239 ) (1,125 ) (275 ) (309 ) Settlements (48 ) (34 ) (4 ) — Fair value of net plan assets at end of year $ 16,678 $ 18,573 $ 2,408 $ 2,732 __________ (a) The pension actuarial gain in 2018 primarily reflects an increase in the discount rate. The OPEB actuarial gain in 2018 primarily reflects an increase in the discount rate and favorable health care claims experience. The pension and OPEB actuarial losses in 2017 primarily reflect a decrease in the discount rate. (b) Exelon recorded pension and OPEB obligations associated with its acquisition of Fitzpatrick on March 31, 2017. Exelon presents its benefit obligations and plan assets net on its balance sheet within the following line items: Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2018 2017 Other current liabilities $ 26 $ 28 $ 33 $ 31 Pension obligations 3,988 3,736 — — Non-pension postretirement benefit obligations — — 1,928 2,093 Unfunded status (net benefit obligation less plan assets) $ 4,014 $ 3,764 $ 1,961 $ 2,124 The funded status of the pension and other postretirement benefit obligations refers to the difference between plan assets and estimated obligations of the plan. The funded status changes over time due to several factors, including contribution levels, assumed discount rates and actual returns on plan assets. The following tables provide the projected benefit obligations (PBO), accumulated benefit obligation (ABO), and fair value of plan assets for all pension plans with a PBO or ABO in excess of plan assets. PBO in excess of plan assets Exelon 2018 2017 Projected benefit obligation $ 20,692 $ 22,337 Fair value of net plan assets 16,678 18,573 ABO in excess of plan assets Exelon 2018 2017 Projected benefit obligation $ 20,692 $ 22,337 Accumulated benefit obligation 19,656 21,153 Fair value of net plan assets 16,678 18,573 On a PBO basis, the Exelon plans were funded at 81% and 83% at December 31, 2018 and 2017 , respectively. On an ABO basis, the Exelon plans were funded at 85% and 88% at December 31, 2018 and 2017 , respectively. The ABO differs from the PBO in that the ABO includes no assumption about future compensation levels. Components of Net Periodic Benefit Costs The majority of the 2018 pension benefit cost for the Exelon-sponsored plans is calculated using an expected long-term rate of return on plan assets of 7.00% and a discount rate of 3.62% . The majority of the 2018 other postretirement benefit cost is calculated using an expected long-term rate of return on plan assets of 6.60% for funded plans and a discount rate of 3.61% . A portion of the net periodic benefit cost for all plans is capitalized within the Consolidated Balance Sheets. The following tables present the components of Exelon’s net periodic benefit costs, prior to capitalization, for the years ended December 31, 2018 , 2017 and 2016 and PHI's net periodic benefit costs, prior to capitalization, for the predecessor period of January 1, 2016 to March 23, 2016 . Pension Benefits Other Postretirement Benefits Exelon 2018 2017 (a) 2016 (b) 2018 2017 (a) 2016 (b) Components of net periodic benefit cost: Service cost $ 405 $ 387 $ 354 $ 112 $ 106 $ 107 Interest cost 802 842 830 175 182 185 Expected return on assets (1,252 ) (1,196 ) (1,141 ) (173 ) (162 ) (162 ) Amortization of: Prior service cost (credit) 2 1 14 (186 ) (188 ) (185 ) Actuarial loss 629 607 554 66 61 63 Settlement and other charges (c) 3 3 2 1 — — Net periodic benefit cost $ 589 $ 644 $ 613 $ (5 ) $ (1 ) $ 8 __________ (a) FitzPatrick net benefit costs are included for the period after acquisition. (b) PHI net periodic benefit costs for the period prior to the merger are not included in the table above. (c) 2016 amount includes an additional termination benefit for PHI. Predecessor Pension Benefits Other PHI January 1, 2016 to March 23, 2016 January 1, 2016 to March 23, 2016 Components of net periodic benefit cost: Service cost $ 12 $ 1 Interest cost 26 6 Expected return on assets (30 ) (5 ) Amortization of: Prior service cost (credit) — (3 ) Actuarial loss 14 2 Net periodic benefit cost $ 22 $ 1 Components of AOCI and Regulatory Assets Under the authoritative guidance for regulatory accounting, a portion of current year actuarial gains and losses and prior service costs (credits) is capitalized within Exelon’s Consolidated Balance Sheets to reflect the expected regulatory recovery of these amounts, which would otherwise be recorded to AOCI. The following tables provide the components of AOCI and regulatory assets (liabilities) for the years ended December 31, 2018 , 2017 and 2016 for all plans combined and the components of PHI's predecessor AOCI and regulatory assets (liabilities) for the period January 1, 2016 to March 23, 2016 . Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2016 (a) 2018 2017 2016 (a) Changes in plan assets and benefit obligations recognized in AOCI and regulatory assets (liabilities): Current year actuarial (gain) loss $ 635 $ (222 ) $ 644 $ (232 ) $ 166 $ (101 ) Amortization of actuarial loss (629 ) (607 ) (554 ) (66 ) (61 ) (63 ) Current year prior service cost (credit) (4 ) 9 (60 ) — — — Amortization of prior service (cost) credit (2 ) (1 ) (14 ) 186 188 185 Settlements (3 ) (3 ) — — — — Acquisitions — — 994 — — 94 Total recognized in AOCI and regulatory assets (liabilities) $ (3 ) $ (824 ) $ 1,010 $ (112 ) $ 293 $ 115 Total recognized in AOCI $ 3 $ (401 ) $ 51 $ (55 ) $ 168 $ 20 Total recognized in regulatory assets (liabilities) $ (6 ) $ (423 ) $ 959 $ (57 ) $ 125 $ 95 Predecessor Pension Benefits Other PHI January 1, 2016 to March 23, 2016 January 1, 2016 to March 23, 2016 Changes in plan assets and benefit Current year actuarial loss (gain) $ — $ — Amortization of actuarial loss (14 ) (2 ) Amortization of prior service (cost) credit — 3 Total recognized in AOCI and regulatory assets (liabilities) $ (14 ) $ 1 Total recognized in AOCI $ (1 ) $ — Total recognized in regulatory assets (liabilities) $ (13 ) $ 1 __________ (a) 2016 amounts include PHI for the period of March 24, 2016 through December 31, 2016. The following table provides the components of gross accumulated other comprehensive loss and regulatory assets (liabilities) that have not been recognized as components of periodic benefit cost at December 31, 2018 and 2017 , respectively, for all plans combined: Exelon Exelon Pension Benefits Other Postretirement Benefits 2018 2017 2018 2017 Prior service (credit) cost $ (29 ) $ (24 ) $ (337 ) $ (522 ) Actuarial loss 7,558 7,556 531 829 Total $ 7,529 $ 7,532 $ 194 $ 307 Total included in AOCI $ 3,899 $ 3,896 $ 70 $ 125 Total included in regulatory assets (liabilities) $ 3,630 $ 3,636 $ 124 $ 182 Average Remaining Service Period For pension benefits, Exelon amortizes its unrecognized prior service costs and certain actuarial gains and losses, as applicable, based on participants’ average remaining service periods. The average remaining service period of Exelon's defined benefit pension plan participants was 12.0 years, 11.8 years and 11.9 years for the years ended December 31, 2018 , 2017 and 2016 , respectively. For other postretirement benefits, Exelon amortizes its unrecognized prior service costs over participants’ average remaining service period to benefit eligibility age and amortizes certain actuarial gains and losses over participants’ average remaining service period to expected retirement. The average remaining service period of postretirement benefit plan participants related to benefit eligibility age was 8.8 years, 8.8 years and 9.0 years for the years ended December 31, 2018 , 2017 and 2016 , respectively. The average remaining service period of postretirement benefit plan participants related to expected retirement was 9.5 years, 9.6 years and 9.7 years for the years ended December 31, 2018 , 2017 and 2016 , respectively. Assumptions The measurement of the plan obligations and costs of providing benefits under Exelon’s defined benefit and other postretirement plans involves various factors, including the development of valuation assumptions and inputs and accounting policy elections. The measurement of benefit obligations and costs is impacted by several assumptions and inputs, including the discount rate applied to benefit obligations, the long-term EROA, Exelon’s expected level of contributions to the plans, the long-term expected investment rate credited to employees participating in cash balance plans and the anticipated rate of increase of health care costs. Additionally, assumptions related to plan participants include the incidence of mortality, the expected remaining service period, the level of compensation and rate of compensation increases, employee age and length of service, among other factors. When developing the required assumptions, Exelon considers historical information as well as future expectations. Expected Rate of Return. In selecting the EROA, Exelon considers historical economic indicators (including inflation and GDP growth) that impact asset returns, as well as expectations regarding future long-term capital market performance, weighted by Exelon’s target asset class allocations. Mortality . The mortality assumption is composed of a base table that represents the current expectation of life expectancy of the population adjusted by an improvement scale that attempts to anticipate future improvements in life expectancy. Exelon’s mortality assumption is supported by an actuarial experience study of Exelon's plan participants and utilizes the IRS's RP–2000 base table projected to 2012 with improvement scale AA and projected thereafter with generational improvement scale BB two-dimensional adjusted to a 0.75% long-term rate reached in 2027. There were no changes to the mortality assumption in 2016 , 2017 or 2018 . The following assumptions were used to determine the benefit obligations for the plans at December 31, 2018 , 2017 and 2016 . Assumptions used to determine year-end benefit obligations are the assumptions used to estimate the subsequent year’s net periodic benefit costs. Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2016 (f) 2018 2017 2016 (f) Discount rate 4.31 % (a) 3.62 % (b) 4.04 % (c) 4.30 % (a) 3.61 % (b) 4.04 % (c) Investment Crediting Rate 4.46 % 4.00 % 4.46 % N/A N/A N/A Rate of compensation increase (d) (d) (e) (d) (d) (e) Mortality table RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) Health care cost trend on covered charges N/A N/A N/A 5.00% with ultimate trend of 5.00% in 2017 5.00% with 5.00% __________ (a) The discount rates above represent the blended rates used to determine the majority of Exelon’s pension and other postretirement benefits obligations as of December 31, 2018 . Certain benefit plans used individual rates ranging from 4.13% - 4.36% and 4.27% - 4.38% for pension and other postretirement plans, respectively. (b) The discount rates above represent the blended rates used to determine the majority of Exelon’s pension and other postretirement benefits obligations as of December 31, 2017 . Certain benefit plans used individual rates ranging from 3.49% - 3.65% and 3.57% - 3.68% for pension and other postretirement plans, respectively. (c) The discount rates above represent the blended rates used to determine the majority of Exelon’s pension and other postretirement benefits obligations as of December 31, 2016 . Certain benefit plans used individual rates ranging from 3.66% - 4.11% and 4.00% - 4.17% for pension and other postretirement plans, respectively. (d) 3.25% through 2019 and 3.75% thereafter. (e) The legacy Exelon, CEG and CENG pension and other postretirement plans used a rate of compensation increase of 3.25% through 2019 and 3.75% thereafter, while the legacy PHI pension and other postretirement plans used a weighted-average rate of compensation increase of 5% for all periods. (f) Obligation was not remeasured for the PHI predecessor for the period from January 1, 2016, to March 23, 2016. The following assumptions were used to determine the net periodic benefit costs for the plans for the years ended December 31, 2018 , 2017 and 2016 , as well as for the PHI predecessor period January 1, 2016 to March 23, 2016 : Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2016 2018 2017 2016 Discount rate 3.62 % (a) 4.04 % (b) 4.29 % (c) 3.61 % (a) 4.04 % (b) 4.29 % (c) Investment Crediting Rate 4.00 % 4.46 % 5.31 % N/A N/A N/A Expected return on plan assets 7.00 % (d) 7.00 % (d) 7.00 % (d) 6.60 % (d) 6.58 % (d) 6.71 % (d) Rate of compensation increase (f) (f) (e) Mortality table RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) Health care cost trend on covered charges N/A N/A N/A 5.00% with ultimate trend of 5.00% in 2017 5.00% 5.50% Predecessor Pension Benefits Other Postretirement Benefits PHI January 1, 2016 to March 23, 2016 January 1, 2016 to March 23, 2016 Discount rate 4.65%/4.55% (g) 4.55 % Investment crediting rate 2.89 % N/A Expected return on plan assets (h) 6.50 % 6.75 % Rate of compensation 5.00 % 5.00 % Mortality table RP-2014 table with improvement scale MP-2015 RP-2014 table with improvement scale MP-2015 Health care cost trend on covered charges N/A 6.33% pre-65 and 5.40% post-65 decreasing to ultimate trend of 5.00% in 2020 __________ (a) The discount rates above represent the blended rates used to establish the majority of Exelon’s pension and other postretirement benefits costs for the year ended December 31, 2018 . Certain benefit plans used individual rates ranging from 3.49% - 3.65% and 3.57% - 3.68% for pension and other postretirement plans, respectively. (b) The discount rates above represent the blended rates used to establish the majority of Exelon's pension and other postretirement benefits costs for the year ended December 31, 2017 . Certain benefit plans used individual rates ranging from 3.66% - 4.11% and 4.00% - 4.17% for pension and other postretirement plans, respectively. (c) The discount rates above represent the blended rates used to establish the majority of Exelon’s pension and other postretirement benefits costs for the year ended December 31, 2016 . Certain benefit plans used the individual rates ranging from 3.68% - 4.14% and 4.32% - 4.43% for pension and other postretirement plans, respectively. (d) Not applicable to pension and other postretirement benefit plans that do not have plan assets. (e) 3.25% through 2019 and 3.75% thereafter. (f) The legacy Exelon, CEG and CENG pension and other postretirement plans used a rate of compensation increase of 3.25% through 2019 and 3.75% thereafter, while the legacy PHI pension and other postretirement plans used a weighted-average rate of compensation increase of 5% for all periods. (g) The discount rate for the qualified and non-qualified pension plans was 4.65% and 4.55% , respectively. (h) Expected return on other postretirement benefit plan assets is pre-tax. Contributions The following tables provide contributions to the pension and other postretirement benefit plans: Pension Benefits Other Postretirement Benefits 2018 (a) 2017 (a) 2016 (a) 2018 2017 2016 Exelon $ 337 $ 341 $ 347 $ 46 $ 64 $ 50 Generation 128 137 140 11 11 12 ComEd 38 36 33 4 5 5 PECO 28 24 30 — — — BGE 40 39 31 14 14 18 BSC (b) 41 38 39 5 2 3 Pepco 6 62 24 11 10 8 DPL — — 22 — 2 — ACE 6 — 15 — 20 2 PHISCO (c) 50 5 17 1 — 2 Pension Benefits Other Postretirement Benefits Successor Predecessor Successor Predecessor 2018 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 2018 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 PHI $ 62 $ 67 $ 74 $ 4 $ 12 $ 32 $ 12 $ — __________ (a) Exelon's and Generation's pension contributions include $21 million and $25 million related to the legacy CENG plans that was funded by CENG as provided in an Employee Matters Agreement (EMA) between Exelon and CENG for the years ended December 31, 2017 and 2016 , respectively. There were no pension contributions for the year ended December 31, 2018 . (b) Includes $2 million , $4 million , and $6 million of pension contributions funded by Exelon Corporate, for the years ended December 31, 2018 , 2017 , and 2016 , respectively. (c) PHISCO’s pension contributions for the year ended December 31, 2016 include $4 million of contributions made prior to the closing of Exelon’s merger with PHI on March 23, 2016 . Management considers various factors when making pension funding decisions, including actuarially determined minimum contribution requirements under ERISA, contributions required to avoid benefit restrictions and at-risk status as defined by the Pension Protection Act of 2006 (the Act), management of the pension obligation and regulatory implications. The Act requires the attainment of certain funding levels to avoid benefit restrictions (such as an inability to pay lump sums or to accrue benefits prospectively), and at-risk status (which triggers higher minimum contribution requirements and participant notification). The projected contributions below reflect a funding strategy of contributing the greater of (1) $300 million until all the qualified plans are fully funded on an ABO basis, and (2) the minimum amounts under ERISA to meet minimum contribution requirement and/or avoid benefit restrictions and at-risk status. This level funding strategy helps minimize volatility of future period required pension contributions. Unlike the qualified pension plans, Exelon’s non-qualified pension plans are not funded, given that they are not subject to statutory minimum contribution requirements. While other postretirement plans are also not subject to statutory minimum contribution requirements, Exelon does fund certain of its plans. For Exelon's funded OPEB plans, contributions generally equal accounting costs, however, Exelon’s management has historically considered several factors in determining the level of contributions to its other postretirement benefit plans, including liabilities management, levels of benefit claims paid and regulatory implications (amounts deemed prudent to meet regulatory expectations and best assure continued rate recovery). The amounts below include benefit payments related to unfunded plans. The following table provides all registrants' planned contributions to the qualified pension plans, planned benefit payments to non-qualified pension plans, and planned contributions to other postretirement plans in 2019: Qualified Pension Plans Non-Qualified Pension Plans Other Exelon $ 301 $ 25 $ 44 Generation 135 7 13 ComEd 65 1 2 PECO 25 1 — BGE 34 1 15 BSC 41 7 2 PHI 1 8 12 Pepco — 2 10 DPL — 1 — ACE — — 1 PHISCO 1 5 1 Estimated Future Benefit Payments Estimated future benefit payments to participants in all of the pension plans and postretirement benefit plans at December 31, 2018 were: Pension Benefits Other Postretirement Benefits 2019 $ 1,196 $ 255 2020 1,221 263 2021 1,258 269 2022 1,284 274 2023 1,302 282 2024 through 2028 6,770 1,483 Total estimated future benefit payments through 2028 $ 13,031 $ 2,826 Allocation to Exelon Subsidiaries All registrants account for their participation in Exelon’s pension and other postretirement benefit plans by applying multi-employer accounting. Employee-related assets and liabilities, including both pension and postretirement liabilities, for the legacy Exelon plans were allocated by Exelon to its subsidiaries based on the number of active employees as of January 1, 2001 as part of Exelon’s corporate restructuring. The obligation for Generation, ComEd and PECO reflects the initial allocation and the cumulative costs incurred and contributions made since January 1, 2001. Historically, Exelon has allocated the components of pension and other postretirement costs to the subsidiaries in the legacy Exelon plans based upon several factors, including the measures of active employee participation in each plan. Pension and other postretirement benefit contributions were allocated to legacy Exelon subsidiaries in proportion to active service costs recognized and total costs recognized, respectively. Beginning in 2015, Exelon began allocating costs related to its legacy Exelon pension and other postretirement benefit plans to its subsidiaries based on both active and retired employee participation and contributions are allocated based on accounting cost. The impact of this allocation methodology change was not material to any Registrant. For legacy CEG, legacy CENG, FitzPatrick, and legacy PHI plans, components of pension and other postretirement benefit costs and contributions have been, and will continue to be, allocated to the subsidiaries based on employee participation (both active and retired). The amounts below represent the Registrants’ as well as BSC's and PHISCO's pension and OPEB costs. As a result of new pension guidance effective on January 1, 2018, certain balances have been reclassified on Exelon’s Consolidated Statements of Operations and Comprehensive Income for the years ended December 31, 2017 and 2016. For Exelon, the service cost component is included in Operating and maintenance expense and Property, plant and equipment, net, for the years ended December 31, 2018, 2017 and 2016, while the non–service cost components are included in Other, net and Regulatory assets for year ended December 31, 2018 and in Other, net and Property, plant and equipment, net, for the years ended December 31, 2017 and 2016. For Generation and the Utility Registrants, the service cost and non–service cost components are included in Operating and maintenance expense and Property, plant and equipment, net on their consolidated financial statements for the years ended December 31, 2018 , 2017 and 2016 . For the Years Ended December 31, Exelon Generation (a) ComEd PECO BGE BSC (b) Pepco (c) DPL (c) ACE (c) PHISCO (c)(d) 2018 $ 583 $ 204 $ 177 $ 18 $ 60 $ 57 $ 15 $ 6 $ 12 $ 34 2017 643 227 176 29 64 53 25 13 13 43 2016 621 218 166 33 68 48 31 18 15 47 Successor Predecessor PHI For the Year Ended December 31, 2018 For the Year Ended December 31, 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Pension and Other Postretirement Benefit Costs $ 67 $ 94 $ 88 $ 23 __________ (a) FitzPatrick net benefit costs are included for the period after acquisition. (b) These amounts primarily represent amounts billed to Exelon’s subsidiaries through intercompany allocations. These amounts are not included in the Generation, ComEd, PECO, BGE, PHI, Pepco, DPL or ACE amounts above. (c) Pepco's, DPL's, ACE's and PHISCO's pension and postretirement benefit costs for the year ended December 31, 2016 include $7 million , $4 million , $3 million and $9 million , respectively, of costs incurred prior to the closing of Exelon’s merger with PHI on March 23, 2016 . (d) These amounts represent amounts billed to Pepco, DPL and ACE through intercompany allocations. These amounts are not included in Pepco, DPL or ACE amounts above. Plan Assets Investment Strategy. On a regular basis, Exelon evaluates its investment strategy to ensure that plan assets will be sufficient to pay plan benefits when due. As part of this ongoing evaluation, Exelon may make changes to its targeted asset allocation and investment strategy. Exelon has developed and implemented a liability hedging investment strategy for its qualified pension plans that has reduced the volatility of its pension assets relative to its pension liabilities. Exelon is likely to continue to gradually increase the liability hedging portfolio as the funded status of its plans improves. The overall objective is to achieve attractive risk-adjusted returns that will balance the liquidity requirements of the plans’ liabilities while striving to minimize the risk of significant losses. Trust assets for Exelon’s other postretirement plans are managed in a diversified investment strategy that prioritizes maximizing liquidity and returns while minimizing asset volatility. Actual asset returns have an impact on the costs reported for the Exelon-sponsored pension and other postretirement benefit plans. The actual asset returns across Exelon’s pension and other postretirement benefit plans for the year ended December 31, 2018 were (4.86)% and (4.66)% , respectively, compared to an expected long-term return assumption of 7.00% and 6.60% , respectively. Exelon used an EROA |
Severance (All Registrants)
Severance (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Restructuring and Related Activities [Abstract] | |
Severance (All Registrants) | The Registrants have an ongoing severance plan under which, in general, the longer an employee worked prior to termination the greater the amount of severance benefits. The Registrants record a liability and expense or regulatory asset for severance once terminations are probable of occurrence and the related severance benefits can be reasonably estimated. For severance benefits that are incremental to its ongoing severance plan (“one-time termination benefits”), the Registrants measure the obligation and record the expense at fair value at the communication date if there are no future service requirements, or, if future service is required to receive the termination benefit, ratably over the required service period. Severance Liability Amounts included in the table below represent the severance liability recorded for employees of each Registrant. Exelon's severance liability includes amounts related to BSC that are billed through intercompany allocations . Severance Liability Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Balance at December 31, 2016 $ 88 $ 36 $ 3 $ — $ — $ 29 $ — $ — $ — Severance costs (a) 35 31 2 — — 3 — — — Payments (29 ) (9 ) (2 ) — — (12 ) — — — Balance at December 31, 2017 $ 94 $ 58 $ 3 $ — $ — $ 20 $ — $ — $ — Severance costs (a) 35 9 1 — 1 5 1 — — Payments (52 ) (20 ) (2 ) — — (18 ) (1 ) — — Balance at December 31, 2018 $ 77 $ 47 $ 2 $ — $ 1 $ 7 $ — $ — $ — __________ (a) Includes salary continuance and health and welfare severance benefits. Severance Costs Related to the PHI Merger Upon closing the PHI Merger, Exelon recorded a severance accrual for the anticipated employee position reductions as a result of the post-merger integration. Cash payments under the plan began in May 2016 and will continue through 2020. For the years ended December 31, 2018 and December 31, 2017 , the PHI Merger severance costs were immaterial. For the year ended December 31, 2016 , the Registrants recorded the following severance costs associated with the identified job reductions within Operating and maintenance expense in their Consolidated Statements of Operations and Comprehensive Income: Severance Benefits Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Severance costs (a) $ 57 $ 9 $ 2 $ 1 $ 1 $ 44 $ 21 $ 13 $ 10 (a) The amounts above for Generation, ComEd, PECO, BGE, Pepco, DPL, and ACE include $8 million , $2 million , $1 million , $1 million , $20 million , $12 million and $10 million , respectively, for amounts billed by BSC and/or PHISCO through intercompany allocations. PHI, Pepco, DPL and ACE recorded regulatory assets for merger related integration costs which include a portion of these severance costs. These regulatory assets are either currently being recovered in rates or are deemed probable of recovery in future rates. See Note 4 — Regulatory Matters for additional information. |
Shareholder Equity (All Registr
Shareholder Equity (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Equity [Abstract] | |
Stockholders' Equity Note Disclosure [Text Block] | Shareholders' Equity (Exelon, ComEd, PECO, BGE, Pepco, DPL and ACE) The following table presents common stock authorized and outstanding as of December 31, 2018 and 2017 : December 31, 2018 2017 Par Value Shares Authorized Shares Outstanding Common Stock Exelon no par value 2,000,000,000 968,187,955 963,335,888 ComEd $ 12.50 250,000,000 127,021,331 127,021,246 PECO no par value 500,000,000 170,478,507 170,478,507 BGE no par value 1,500 1,000 1,000 Pepco $ 0.01 200,000,000 100 100 DPL $ 2.25 1,000 1,000 1,000 ACE $ 3.00 25,000,000 8,546,017 8,546,017 ComEd had 60,285 and 60,584 warrants outstanding to purchase ComEd common stock at December 31, 2018 and 2017 , respectively. The warrants entitle the holders to convert such warrants into common stock of ComEd at a conversion rate of one share of common stock for three warrants. At December 31, 2018 and 2017 , 20,095 and 20,195 shares of common stock, respectively, were reserved for the conversion of warrants. Equity Securities Offering In June 2014, Exelon marketed an equity offering of 57.5 million shares of its common stock at a public offering price of $35 per share. In connection with such offering, Exelon entered into forward sale agreements with two counterparties. In July 2015, Exelon settled the forward sale agreement by the issuance of 57.5 million shares of Exelon common stock. Exelon received net cash proceeds of $1.87 billion , which was calculated based on a forward price of $32.48 per share as specified in the forward sale agreements. The net proceeds were used to fund the merger with PHI and related costs and expenses, and for general corporate purposes. The forward sale agreements are classified as equity transactions. As a result, no amounts were recorded in the consolidated financial statements until the July 2015 settlement of the forward sale agreements. However, prior to the July 2015 settlement, incremental shares, if any, were included within the calculation of diluted EPS using the treasury stock method. Concurrent with the forward equity transaction, Exelon also issued $1.15 billion of junior subordinated notes in the form of 23 million equity units. On June 1, 2017, Exelon settled the forward purchase contract, which was a component of the June 2014 equity units, through the issuance of Exelon common stock from treasury stock. See Note 13 — Debt and Credit Agreements for additional information on the equity units. Share Repurchases Share Repurchase Programs There currently is no Exelon Board of Director authority to repurchase shares. Any previous shares repurchased are held as treasury shares, at cost, unless cancelled or reissued at the discretion of Exelon’s management. Under the previous share repurchase programs, 2 million shares of common stock were held as treasury stock with a historical cost of $123 million at December 31, 2018 and 2017 . During 2017 , Exelon issued approximately 33 million shares of Exelon common stock from treasury stock in order to settle the forward purchase contract, which was a component of the June 2014 equity units discussed above. During 2018 , 2017 , and 2016 Exelon had no common stock repurchases. Preferred and Preference Securities of Subsidiaries At December 31, 2018 and 2017 , Exelon was authorized to issue up to 100,000,000 shares of preferred securities, none of which were outstanding. At December 31, 2018 and 2017 , ComEd prior preferred securities and ComEd cumulative preference securities consisted of 850,000 shares and 6,810,451 shares authorized, respectively, none of which were outstanding. BGE had $190 million of cumulative preference stock that was redeemable at its option at any time after October 1, 2015 for the redemption price of $100 per share, plus accrued and unpaid dividends. On July 3, 2016, BGE redeemed all 400,000 shares of its outstanding 7.125% Cumulative Preference Stock, 1993 Series and all 600,000 shares of its outstanding 6.990% Cumulative Preference Stock, 1995 Series for $100 million , plus accrued and unpaid dividends. On September 18, 2016, BGE redeemed the remaining 500,000 shares of its outstanding 6.970% Cumulative Preference Stock, 1993 Series and the remaining 400,000 shares of its outstanding 6.700% Cumulative Preference Stock, 1993 Series for $90 million , plus accrued and unpaid dividends. |
Stock-Based Compensation Plans
Stock-Based Compensation Plans (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Common Stock [Abstract] | |
Stock-Based Compensation Plans | Stock-Based Compensation Plans (All Registrants) Stock-Based Compensation Plans Exelon grants stock-based awards through its LTIP, which primarily includes stock options, restricted stock units and performance share awards. At December 31, 2018 , there were approximately 11 million shares authorized for issuance under the LTIP. For the years ended December 31, 2018 , 2017 and 2016 , exercised and distributed stock-based awards were primarily issued from authorized but unissued common stock shares. ComEd, PECO, BGE and PHI grant cash awards. The following tables do not include expense related to these plans as they are not considered stock-based compensation plans under the applicable authoritative guidance . In connection with the acquisition of PHI in March 2016, PHI’s unvested time-based restricted stock units and performance-based restricted stock units issued prior to April 29, 2014 were immediately vested and paid in cash upon the close of the merger. PHI’s remaining unvested time-based restricted stock units as of the close of the merger were cancelled. There were no remaining unvested performance-based restricted stock units as of the close of the merger. For the years ended December 31, 2018 , 2017 and 2016 , there were no significant modifications to the granted stock based awards. The following tables present the stock-based compensation expense included in Exelon's and PHI’s Consolidated Statements of Operations and Comprehensive Income for the years ended December 31, 2018 , 2017 and 2016 and PHI's predecessor period January 1, 2016 to March 23, 2016 : Exelon Year Ended December 31, Components of Stock-Based Compensation Expense 2018 2017 2016 (a) Performance share awards $ 143 $ 107 $ 93 Restricted stock units 57 77 75 Stock options — — — Other stock-based awards 8 7 7 Total stock-based compensation expense included in operating and maintenance expense 208 191 175 Income tax benefit (54 ) (74 ) (68 ) Total after-tax stock-based compensation expense $ 154 $ 117 $ 107 __________ (a) 2016 amounts include expense related to stock-based compensation granted to eligible PHI employees since the merger date of March 23, 2016 . PHI Predecessor January 1 to March 23, Components of Stock-Based Compensation Expense 2016 Time-based restricted stock units $ 2 Performance-based restricted stock units 1 Time-based restricted stock awards — Total stock-based compensation expense included in operating and maintenance expense 3 Income tax benefit (1 ) Total after-tax stock-based compensation expense $ 2 The following tables present the Registrants' stock-based compensation expense (pre-tax) for the years ended December 31, 2018 , 2017 and 2016 , as well as for the PHI predecessor period January 1, 2016 to March 23, 2016 : Year Ended December 31, Subsidiaries 2018 2017 2016 Exelon $ 208 $ 191 $ 175 Generation 77 88 78 ComEd 8 7 8 PECO 5 3 3 BGE 3 1 1 BSC (a) 111 88 81 PHI Successor (b)(c) 4 4 4 Predecessor January 1 to 2016 PHI $ 3 __________ (a) These amounts primarily represent amounts billed to Exelon’s subsidiaries through intercompany allocations. These amounts are not included in the Generation, ComEd, PECO, BGE or PHI amounts above. (b) Pepco's, DPL's and ACE's stock-based compensation expense for the years ended December 31, 2018 and 2017 was not material. (c) These amounts primarily represent amounts billed to PHI’s subsidiaries through PHISCO intercompany allocations. There were no significant stock-based compensation costs capitalized during the years ended December 31, 2018 , 2017 and 2016 for Exelon or PHI, or for PHI during the predecessor period January 1, 2016 to March 23, 2016 . Exelon receives a tax deduction based on the intrinsic value of the award on the exercise date for stock options and the distribution date for performance share awards and restricted stock units. For each award, throughout the requisite service period, Exelon recognizes the tax benefit related to compensation costs. The following tables present information regarding Exelon’s tax benefits for the years ended December 31, 2018 , 2017 and 2016 . Exelon Year Ended December 31, 2018 2017 2016 Realized tax benefit when exercised/distributed: Restricted stock units 28 35 27 Performance share awards 16 29 18 Stock Options Non-qualified stock options to purchase shares of Exelon’s common stock were granted under the LTIP through 2012. Due to changes in the LTIP, there were no stock options granted in 2018 , 2017 and 2016 . For all stock options granted through 2012, the exercise price of the stock options is equal to the fair market value of the underlying stock on the date of option grant. The vesting period of stock options is generally four years and all stock options will expire no later than ten years from the date of grant. The value of stock options at the date of grant is expensed over the requisite service period using the straight-line method. The requisite service period for stock options is generally four years . However, certain stock options become fully vested upon the employee reaching retirement-eligibility. The value of the stock options granted to retirement-eligible employees is either recognized immediately upon the date of grant or through the date at which the employee reaches retirement eligibility. The following table presents information with respect to stock option activity for the year ended December 31, 2018 : Shares Weighted Average Exercise Price (per share) Weighted Average Remaining Contractual Life (years) Aggregate Intrinsic Value Balance of shares outstanding at December 31, 2017 6,723,611 $ 47.69 2.65 $ 7 Options exercised (1,522,952 ) 36.54 Options forfeited — — Options expired (1,173,007 ) 74.99 Balance of shares outstanding at December 31, 2018 4,027,652 $ 43.95 2.90 $ 14 Exercisable at December 31, 2018 (a) 4,027,652 $ 43.95 2.90 $ 14 __________ (a) Includes stock options issued to retirement eligible employees. The following table summarizes additional information regarding stock options exercised for the years ended December 31, 2018 , 2017 and 2016 : Year Ended 2018 2017 2016 Intrinsic value (a) $ 12 $ 15 $ 11 Cash received for exercise price 56 107 19 __________ (a) The difference between the market value on the date of exercise and the option exercise price. At December 31, 2016 , all stock options were vested and at December 31, 2018 there were no unrecognized compensation costs related to nonvested stock options. Restricted Stock Units Restricted stock units are granted under the LTIP with the majority being settled in a specific number of shares of common stock after the service condition has been met. The corresponding cost of services is measured based on the grant date fair value of the restricted stock unit issued. The value of the restricted stock units is expensed over the requisite service period using the straight-line method. The requisite service period for restricted stock units is generally three to five years . However, certain restricted stock unit awards become fully vested upon the employee reaching retirement-eligibility. The value of the restricted stock units granted to retirement-eligible employees is either recognized immediately upon the date of grant or through the date at which the employee reaches retirement eligibility. Exelon processes forfeitures as they occur for employees who do not complete the requisite service period. The following table summarizes Exelon’s nonvested restricted stock unit activity for the year ended December 31, 2018 : Exelon Shares Weighted Average Grant Date Fair Value (per share) Nonvested at December 31, 2017 (a) 3,389,503 $ 32.24 Granted 1,321,988 38.60 Vested (1,845,300 ) 32.03 Forfeited (65,046 ) 32.96 Undistributed vested awards (b) (507,804 ) 36.76 Nonvested at December 31, 2018 (a) 2,293,341 $ 35.06 __________ (a) Excludes 1,131,487 and 1,488,383 of restricted stock units issued to retirement-eligible employees as of December 31, 2018 and 2017 , respectively, as they are fully vested. (b) Represents restricted stock units that vested but were not distributed to retirement-eligible employees during 2018 . For Exelon, the weighted average grant date fair value (per share) of restricted stock units granted for the years ended December 31, 2018 , 2017 and 2016 was $38.60 , $34.98 and $28.14 , respectively. At December 31, 2018 and 2017 , Exelon had obligations related to outstanding restricted stock units not yet settled of $83 million and $108 million , respectively, which are included in common stock in Exelon’s Consolidated Balance Sheets. For the years ended December 31, 2018 , 2017 and 2016 , Exelon settled restricted stock units with fair value totaling $106 million , $88 million and $68 million , respectively. At December 31, 2018 , $38 million of total unrecognized compensation costs related to nonvested restricted stock units are expected to be recognized over the remaining weighted-average period of 2.5 years. Performance Share Awards Performance share awards are granted under the LTIP. The performance share awards are settled 50% in common stock and 50% in cash at the end of the three-year performance period, except for awards granted to vice presidents and higher officers that are settled 100% in cash if certain ownership requirements are satisfied. The common stock portion of the performance share awards is considered an equity award and is valued based on Exelon's stock price on the grant date. The cash portion of the performance share awards is considered a liability award which is remeasured each reporting period based on Exelon’s current stock price. As the value of the common stock and cash portions of the awards are based on Exelon’s stock price during the performance period, coupled with changes in the total shareholder return modifier and expected payout of the award, the compensation costs are subject to volatility until payout is established. Effective January 2017 for nonretirement-eligible employees, stock-based compensation costs are recognized over the vesting period of three years using the straight-line method. For performance share awards granted to retirement-eligible employees, the value of the performance shares is recognized ratably over the vesting period, which is the year of grant. In 2016 and prior, for nonretirement-eligible employees, stock-based compensation costs are recognized over the vesting period of three years using the graded-vesting method. For performance share awards granted to retirement-eligible employees, the value of the performance shares is recognized ratably over the vesting period, which is the year of grant. Exelon processes forfeitures as they occur for employees who do not complete the requisite service period. The following table summarizes Exelon’s nonvested performance share awards activity for the year ended December 31, 2018 : Exelon Shares Weighted Average Grant Date Fair Value (per share) Nonvested at December 31, 2017 (a) 2,956,966 $ 32.65 Granted 1,637,542 38.15 Change in performance 1,348,029 30.66 Vested (848,574 ) 36.26 Forfeited (50,467 ) 36.24 Undistributed vested awards (b) (1,640,268 ) 33.38 Nonvested at December 31, 2018 (a) 3,403,228 $ 33.13 __________ (a) Excludes 3,586,259 and 2,723,440 of performance share awards issued to retirement-eligible employees as of December 31, 2018 and 2017 , respectively, as they are fully vested. (b) Represents performance share awards that vested but were not distributed to retirement-eligible employees during 2018 . The following table summarizes the weighted average grant date fair value and the fair value of performance share awards granted and settled for the years ended December 31, 2018 , 2017 and 2016 : Year Ended 2018 (a) 2017 2016 Weighted average grant date fair value (per share) $ 38.15 $ 35.00 $ 28.85 Fair value of performance shares settled 61 72 45 Fair value of performance shares settled in cash 49 56 28 __________ (a) As of December 31, 2018 , $33 million of total unrecognized compensation costs related to nonvested performance shares are expected to be recognized over the remaining weighted-average period of 1.7 years. For PHI, the weighted average grant date fair value (per share) of performance-based restricted stock awards was $26.10 for the year ended December 31, 2016 . There were no time-based restricted stock awards granted for the year ended December 31, 2016 . There were no time-based share settlements or performance-based share settlements for the year-ended December 31, 2016 or the predecessor period January 1, 2016 to March 23, 2016 . The following table presents the balance sheet classification of obligations related to outstanding performance share awards not yet settled: December 31, 2018 2017 Current liabilities (a) $ 135 $ 57 Deferred credits and other liabilities (b) 109 100 Common stock 26 26 Total $ 270 $ 183 __________ (a) Represents the current liability related to performance share awards expected to be settled in cash. (b) Represents the long-term liability related to performance share awards expected to be settled in cash. |
Earnings Per Share (Exelon)
Earnings Per Share (Exelon) | 12 Months Ended |
Dec. 31, 2018 | |
Earnings Per Share [Abstract] | |
Earnings Per Share (Exelon) | Earnings Per Share (Exelon) Basic earnings per share is computed by dividing net income attributable to common stockholders by the weighted average number of common shares outstanding during the period. Diluted earnings per share is computed by dividing net income attributable to common shareholders by the weighted average number of common shares outstanding, including the effect of issuing common stock assuming (i) stock options are exercised, and (ii) performance share awards and restricted stock awards are fully vested under the treasury stock method. The following table sets forth the components of basic and diluted earnings per share and shows the effect of these stock options, performance share awards and restricted stock awards on the weighted average number of shares outstanding used in calculating diluted earnings per share: Year Ended December 31, 2018 2017 2016 Net income attributable to common shareholders $ 2,010 $ 3,786 $ 1,121 Weighted average common shares outstanding — basic 967 947 924 Assumed exercise and/or distributions of stock-based awards 2 2 3 Weighted average common shares outstanding — diluted 969 949 927 The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was approximately 3 million in 2018 , 8 million in 2017 , and 12 million in 2016 . There were no equity units related to the PHI merger not included in the calculation of diluted common shares outstanding due to their antidilutive effect for the years ended December 31, 2018 , 2017 , and 2016 . See Note 18 — Shareholders' Equity for additional information regarding the equity units and equity forward units. On June 1, 2017, Exelon settled the forward purchase contract, which was a component of the June 2014 equity units, through the issuance of approximately 33 million shares of Exelon common stock from treasury stock. The issuance of shares on June 1, 2017 triggered full dilution in the EPS calculation, which prior to settlement were included in the calculation of diluted EPS using the treasury stock method. See Note 18 — Shareholders' Equity for additional information regarding share repurchases. |
Changes in Accumulated Other Co
Changes in Accumulated Other Comprehensive Income (Exelon, Generation, and PECO) | 12 Months Ended |
Dec. 31, 2018 | |
Changes in Accumulated Other Comprehensive Income [Abstract] | |
Changes in Accumulated Other Comprehensive Income (Exelon, Generation, and PECO) | Changes in Accumulated Other Comprehensive Income (Exelon, Generation and PECO) The following tables present changes in accumulated other comprehensive income (loss) (AOCI) by component for the years ended December 31, 2018 and 2017 : For the Year Ended December 31, 2018 Gains and Unrealized Pension and Foreign AOCI of Investments Total Exelon (a) Beginning balance $ (14 ) $ 10 $ (2,998 ) $ (23 ) $ (1 ) $ (3,026 ) OCI before reclassifications 11 — (143 ) (10 ) 1 (141 ) Amounts reclassified from AOCI (b) 1 — 181 — — 182 Net current-period OCI 12 — 38 (10 ) 1 41 Impact of adoption of Recognition and Measurement of Financial Assets and Financial Liabilities standard (c) — (10 ) — — — (10 ) Ending balance $ (2 ) $ — $ (2,960 ) $ (33 ) $ — $ (2,995 ) Generation (a) Beginning balance $ (16 ) $ 3 $ — $ (23 ) $ (1 ) $ (37 ) OCI before reclassifications 11 — — (10 ) — 1 Amounts reclassified from AOCI (b) 1 — — — — 1 Net current-period OCI 12 — — (10 ) — 2 Impact of adoption of Recognition and Measurement of Financial Assets and Financial Liabilities standard (c) — (3 ) — — — (3 ) Ending balance $ (4 ) $ — $ — $ (33 ) $ (1 ) $ (38 ) PECO (a) Beginning balance $ — $ 1 $ — $ — $ — $ 1 OCI before reclassifications — — — — — — Amounts reclassified from AOCI (b) — — — — — — Net current-period OCI — — — — — — Impact of adoption of Recognition and Measurement of Financial Assets and Financial Liabilities standard (c) — (1 ) — — — (1 ) Ending balance $ — $ — $ — $ — $ — $ — For the Year Ended December 31, 2017 Gains and Unrealized Pension and Foreign AOCI of Investments Total Exelon (a) Beginning balance $ (17 ) $ 4 $ (2,610 ) $ (30 ) $ (7 ) $ (2,660 ) OCI before reclassifications (1 ) 6 11 7 6 29 Amounts reclassified from AOCI (b) 4 — 140 — — 144 Net current-period OCI 3 6 151 7 6 173 Impact of adoption of Reclassification of Certain Tax Effects from AOCI (d) — — (539 ) — — (539 ) Ending balance $ (14 ) $ 10 $ (2,998 ) $ (23 ) $ (1 ) $ (3,026 ) Generation (a) Beginning balance $ (19 ) $ 2 $ — $ (30 ) $ (7 ) $ (54 ) OCI before reclassifications (1 ) 1 — 7 6 13 Amounts reclassified from AOCI (b) 4 — — — — 4 Net current-period OCI 3 1 — 7 6 17 Ending balance $ (16 ) $ 3 $ — $ (23 ) $ (1 ) $ (37 ) PECO (a) Beginning balance $ — $ 1 $ — $ — $ — $ 1 OCI before reclassifications — — — — — — Amounts reclassified from AOCI (b) — — — — — — Net current-period OCI — — — — — — Ending balance $ — $ 1 $ — $ — $ — $ 1 __________ (a) All amounts are net of tax and noncontrolling interests. Amounts in parenthesis represent a decrease in AOCI. (b) See next tables for details about these reclassifications. (c) Exelon prospectively adopted the new standard Recognition and Measurement of Financial Assets and Financial Liabilities. The standard was adopted as of January 1, 2018, which resulted in an increase to Retained earnings and Accumulated other comprehensive loss of $10 million , $3 million and $1 million for Exelon, Generation and PECO, respectively. The amounts reclassified related to Rabbi Trusts. See Note 1 — Significant Accounting Policies for additional information. (d) Exelon early adopted the new standard Reclassification of Certain Tax Effects from AOCI. The standard was adopted retrospectively as of December 31, 2017, which resulted in an increase to Exelon’s Retained earnings and Accumulated other comprehensive loss of $539 million , primarily related to deferred income taxes associated with Exelon’s pension and OPEB obligations. See Note 1 — Significant Accounting Policies for additional information. ComEd, PECO, BGE, PHI, Pepco, DPL and ACE did not have any reclassifications out of AOCI to Net income during the years ended December 31, 2018 and 2017 . The following tables present amounts reclassified out of AOCI to Net income for Exelon and Generation during the years ended December 31, 2018 and 2017 : For the Year Ended December 31, 2018 Details about AOCI components Items reclassified out of AOCI (a) Affected line item in the Statement of Operations and Comprehensive Income Exelon Generation Gains (Losses) on cash flow hedges Other cash flow hedges $ (1 ) $ (1 ) Interest expense (1 ) (1 ) Total before tax — — Tax benefit $ (1 ) $ (1 ) Net of tax Amortization of pension and other postretirement benefit plan items Prior service costs (b) $ 90 $ — Actuarial losses (b) (333 ) — (243 ) — Total before tax 62 — Tax benefit $ (181 ) $ — Net of tax Total Reclassifications $ (182 ) $ (1 ) Net of tax For the Year Ended December 31, 2017 Details about AOCI components Items reclassified out of AOCI (a) Affected line item in the Statement of Operations and Comprehensive Income Exelon Generation Gains (Losses) on cash flow hedges Other cash flow hedges $ (5 ) $ (5 ) Interest expense (5 ) (5 ) Total before tax 1 1 Tax benefit $ (4 ) $ (4 ) Net of tax Amortization of pension and other postretirement benefit plan items Prior service costs (b) $ 92 $ — Actuarial losses (b) (324 ) — (232 ) — Total before tax 92 — Tax benefit $ (140 ) $ — Net of tax Total Reclassifications $ (144 ) $ (4 ) Net of tax __________ (a) Amounts in parenthesis represent a decrease in net income. (b) This AOCI component is included in the computation of net periodic pension and OPEB cost. See Note 16 — Retirement Benefits for additional information. The following table presents income tax benefit (expense) allocated to each component of other comprehensive income (loss) during the years ended December 31, 2018 , 2017 and 2016 : For the Year Ended December 31, 2018 2017 2016 Exelon Pension and non-pension postretirement benefit plans: Prior service benefit reclassified to periodic benefit cost $ 24 $ 36 $ 30 Actuarial loss reclassified to periodic benefit cost (86 ) (128 ) (118 ) Pension and non-pension postretirement benefit plans valuation adjustment 50 13 115 Change in unrealized gains on cash flow hedges (5 ) (7 ) — Change in unrealized gains (losses) on investments in unconsolidated affiliates — (3 ) 3 Change in unrealized gains on marketable securities — (1 ) — Total $ (17 ) $ (90 ) $ 30 Generation Change in unrealized gains on cash flow hedges $ (4 ) $ (6 ) $ (2 ) Change in unrealized gains (losses) on investments in unconsolidated affiliates (1 ) (3 ) 3 Change in unrealized gains on marketable securities — (1 ) — Total $ (5 ) $ (10 ) $ 1 |
Commitments and Contingencies (
Commitments and Contingencies (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies (All Registrants) | Commitments and Contingencies (All Registrants) Commitments Constellation Merger Commitments (Exelon and Generation). In February 2012, the MDPSC issued an Order approving the Exelon and Constellation merger. As part of the MDPSC Order, Exelon agreed to provide a package of benefits to BGE customers, the City of Baltimore and the State of Maryland, resulting in an estimated direct investment in the State of Maryland of approximately $1 billion . The direct investment included the construction of a new 21-story headquarters building in Baltimore for Generation’s competitive energy business that was substantially complete in November 2016 and is now occupied by approximately 1,500 Exelon employees. Generation's investment in leasehold improvements totaled approximately $90 million . In addition, Generation entered into a 20 -year operating lease as the primary lessee of the building. The direct investment commitment also included $450 million to $500 million relating to Exelon and Generation’s development or assistance in the development of 285 - 300 MWs of new generation in Maryland, which is expected to be completed within a period of 10 years after the merger. The MDPSC order contemplated various options for complying with the new generation development commitments, including building or acquiring generating assets, making subsidy or compliance payments, or in circumstances in which the generation build is delayed or certain specified provisions are elected, making liquidated damages payments. Exelon and Generation have incurred $458 million towards satisfying the commitment for new generation development in the state of Maryland, with approximately 220 MW of the new generation commencing with commercial operations to date and an additional 10 MW commitment satisfied through a liquidated damages payment made in the fourth quarter of 2016. Additionally, during the fourth quarter of 2016, given continued declines in projected energy and capacity prices, Generation terminated rights to certain development projects originally intended to meet its remaining 55 MW commitment amount. The commitment is expected to be satisfied via payment of liquidated damages or execution of a third party PPA, rather than by Generation constructing renewable generating assets. As a result, Exelon and Generation recorded a pre-tax $50 million loss contingency in Operating and maintenance expense in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income for the year ended December 31, 2016. The remaining commitment is to be paid on or before January 15, 2023 unless the period is extended by consent of Exelon and the State of Maryland. As of December 31, 2018 and 2017 , Exelon's and Generation's Consolidated Balance Sheets include a $50 million liability within Deferred credits and other liabilities for this remaining commitment. Commercial Commitments (All Registrants). Exelon’s commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 1,703 $ 1,394 $ 308 $ 1 $ — $ — $ — Surety bonds (a) 1,402 1,331 33 38 — — — Financing trust guarantees 378 — — — — — 378 Guaranteed lease residual values (b) 24 3 3 2 3 3 10 Total commercial commitments $ 3,507 $ 2,728 $ 344 $ 41 $ 3 $ 3 $ 388 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. (b) Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $61 million , $19 million of which is a guarantee by Pepco, $26 million by DPL and $16 million by ACE. The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and PHI believes the likelihood of payments being required under the guarantees is remote. Generation’s commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 1,680 $ 1,380 $ 299 $ 1 $ — $ — $ — Surety bonds (a) 1,220 1,201 19 — — — — Total commercial commitments $ 2,900 $ 2,581 $ 318 $ 1 $ — $ — $ — __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. ComEd’s commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 2 $ 2 $ — $ — $ — $ — $ — Surety bonds (a) 12 10 — 2 — — — Financing trust guarantees 200 — — — — — 200 Total commercial commitments $ 214 $ 12 $ — $ 2 $ — $ — $ 200 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. PECO’s commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Surety bonds (a) $ 9 $ 9 $ — $ — $ — $ — $ — Financing trust guarantees 178 — — — — — 178 Total commercial commitments $ 187 $ 9 $ — $ — $ — $ — $ 178 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. BGE’s commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 3 $ 2 $ 1 $ — $ — $ — $ — Surety bonds (a) 17 3 14 — — — — Total commercial commitments $ 20 $ 5 $ 15 $ — $ — $ — $ — __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. PHI commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 8 $ — $ 8 $ — $ — $ — $ — Surety bonds (a) $ 41 $ 41 $ — $ — $ — $ — $ — Guaranteed lease residual values (b) 24 3 3 2 3 3 10 Total commercial commitments $ 73 $ 44 $ 11 $ 2 $ 3 $ 3 $ 10 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. (b) Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $61 million . The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and PHI believes the likelihood of payments being required under the guarantees is remote. Pepco commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 8 $ — $ 8 $ — $ — $ — $ — Surety bonds (a) $ 33 $ 33 $ — $ — $ — $ — $ — Guaranteed lease residual values (b) 8 1 1 1 1 1 3 Total commercial commitments $ 49 $ 34 $ 9 $ 1 $ 1 $ 1 $ 3 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. (b) Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $19 million . The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and Pepco believes the likelihood of payments being required under the guarantees is remote. DPL commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Surety bonds (a) $ 5 $ 5 $ — $ — $ — $ — $ — Guaranteed lease residual values (b) 10 1 1 1 1 1 5 Total commercial commitments $ 15 $ 6 $ 1 $ 1 $ 1 $ 1 $ 5 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. (b) Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $26 million . The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and DPL believes the likelihood of payments being required under the guarantees is remote. ACE commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Surety bonds (a) $ 3 $ 3 $ — $ — $ — $ — $ — Guaranteed lease residual values (b) 6 1 1 — 1 1 2 Total commercial commitments $ 9 $ 4 $ 1 $ — $ 1 $ 1 $ 2 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. (b) Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $16 million . The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and ACE believes the likelihood of payments being required under the guarantees is remote. Leases (All Registrants) Minimum future operating lease payments, including lease payments for contracted generation, vehicles, real estate, computers, rail cars, operating equipment and office equipment, as of December 31, 2018 were: Exelon (a)(b) Generation (a)(b) ComEd (a)(c) PECO (a)(c) BGE (a)(c)(d)(e) PHI (a) Pepco (a) DPL (a)(c) ACE (a) 2019 $ 140 $ 33 $ 7 $ 5 $ 35 $ 48 $ 11 $ 14 $ 7 2020 149 46 5 5 35 46 10 13 6 2021 143 46 4 5 33 43 9 12 5 2022 126 47 4 5 18 42 8 12 5 2023 97 46 3 5 3 39 8 10 4 Remaining years 723 545 — — 19 159 40 35 5 Total minimum future lease payments $ 1,378 $ 763 $ 23 $ 25 $ 143 $ 377 $ 86 $ 96 $ 32 __________ (a) Includes amounts related to shared use land arrangements. (b) Excludes Generation’s contingent operating lease payments associated with contracted generation agreements. (c) Amounts related to certain real estate leases and railroad licenses effectively have indefinite payment periods. As a result, ComEd, PECO, BGE and DPL have excluded these payments from the remaining years as such amounts would not be meaningful. ComEd's, PECO’s, BGE’s and DPL's average annual obligation for these arrangements, included in each of the years 2019 - 2023 , was $3 million , $5 million , $1 million and $1 million respectively. Also includes amounts related to shared use land arrangements. (d) Includes all future lease payments on a 99 -year real estate lease that expires in 2106 . (e) The BGE column above includes minimum future lease payments associated with a 6-year lease for the Baltimore City conduit system that became effective during the fourth quarter of 2016. BGE's total commitments under the lease agreement are $26 million , $28 million , $28 million and $14 million related to years 2019 - 2022 , respectively. The following table presents the Registrants’ rental expense under operating leases for the years ended December 31, 2018, 2017 and 2016: For the Year Ended December 31, Exelon Generation (a) ComEd PECO BGE Pepco DPL ACE 2018 $ 670 $ 558 $ 7 $ 10 $ 35 $ 10 $ 13 $ 8 2017 709 578 9 9 32 11 16 14 2016 777 667 15 7 22 8 15 13 Successor Predecessor For the Year Ended December 31, 2018 For the Year Ended December 31, 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 PHI Rental expense under operating leases $ 48 $ 63 $ 49 $ 12 __________ (a) Includes contingent operating lease payments associated with contracted generation agreements that are not included in the minimum future operating lease payments table above. Payments made under Generation’s contracted generation lease agreements totaled $493 million , $508 million and $604 million during 2018 , 2017 and 2016 , respectively. Excludes contract amortization associated with purchase accounting and contract acquisitions. For information regarding capital lease obligations, see Note 13 —Debt and Credit Agreements. Nuclear Insurance (Exelon and Generation) Generation is subject to liability, property damage and other risks associated with major incidents at any of its nuclear stations. Generation has mitigated its financial exposure to these risks through insurance and other industry risk-sharing provisions. The Price-Anderson Act was enacted to ensure the availability of funds for public liability claims arising from an incident at any of the U.S. licensed nuclear facilities and to limit the liability of nuclear reactor owners for such claims from any single incident. As of December 31, 2018 , the current liability limit per incident is $14.1 billion and is subject to change to account for the effects of inflation and changes in the number of licensed reactors at least once every five years with the last adjustment effective November 1, 2018. In accordance with the Price-Anderson Act, Generation maintains financial protection at levels equal to the amount of liability insurance available from private sources through the purchase of private nuclear energy liability insurance for public liability claims that could arise in the event of an incident. Effective January 1, 2017, the required amount of nuclear energy liability insurance purchased is $450 million for each operating site. Claims exceeding that amount are covered through mandatory participation in a financial protection pool, as required by the Price Anderson-Act, which provides the additional $13.6 billion per incident in funds available for public liability claims. Participation in this secondary financial protection pool requires the operator of each reactor to fund its proportionate share of costs for any single incident that exceeds the primary layer of financial protection. Exelon’s share of this secondary layer would be approximately $3.1 billion , however any amounts payable under this secondary layer would be capped at $454 million per year. In addition, the U.S. Congress could impose revenue-raising measures on the nuclear industry to pay public liability claims exceeding the $14.1 billion limit for a single incident. As part of the execution of the NOSA on April 1, 2014, Generation executed an Indemnity Agreement pursuant to which Generation agreed to indemnify EDF and its affiliates against third-party claims that may arise from any future nuclear incident (as defined in the Price-Anderson Act) in connection with the CENG nuclear plants or their operations. Exelon guarantees Generation’s obligations under this indemnity. See Note 2 — Variable Interest Entities for additional information on Generation’s operations relating to CENG. Generation is required each year to report to the NRC the current levels and sources of property insurance that demonstrates Generation possesses sufficient financial resources to stabilize and decontaminate a reactor and reactor station site in the event of an accident. The property insurance maintained for each facility is currently provided through insurance policies purchased from NEIL, an industry mutual insurance company of which Generation is a member. NEIL may declare distributions to its members as a result of favorable operating experience. In recent years NEIL has made distributions to its members, but Generation cannot predict the level of future distributions or if they will continue at all. Generation's portion of the annual distribution declared by NEIL is estimated to be $58 million for 2018 , and was $60 million and $21 million for 2017 and 2016 , respectively. In addition, in March 2018, NEIL declared a supplemental distribution. Generation's portion of the supplemental distribution declared by NEIL was $31 million . The distributions were recorded as a reduction to Operating and maintenance expense within Exelon and Generation’s Consolidated Statements of Operations and Comprehensive Income. Premiums paid to NEIL by its members are also subject to a potential assessment for adverse loss experience in the form of a retrospective premium obligation. NEIL has never assessed this retrospective premium since its formation in 1973, and Generation cannot predict the level of future assessments if any. The current maximum aggregate annual retrospective premium obligation for Generation is approximately $345 million . NEIL requires its members to maintain an investment grade credit rating or to ensure collectability of their annual retrospective premium obligation by providing a financial guarantee, letter of credit, deposit premium, or some other means of assurance. NEIL provides “all risk” property damage, decontamination and premature decommissioning insurance for each station for losses resulting from damage to its nuclear plants, either due to accidents or acts of terrorism. If the decision is made to decommission the facility, a portion of the insurance proceeds will be allocated to a fund, which Generation is required by the NRC to maintain, to provide for decommissioning the facility. In the event of an insured loss, Generation is unable to predict the timing of the availability of insurance proceeds to Generation and the amount of such proceeds that would be available. In the event that one or more acts of terrorism cause accidental property damage within a twelve-month period from the first accidental property damage under one or more policies for all insured plants, the maximum recovery by Exelon will be an aggregate of $ 3.2 billion plus such additional amounts as the insurer may recover for all such losses from reinsurance, indemnity and any other source, applicable to such losses. For its insured losses, Generation is self-insured to the extent that losses are within the policy deductible or exceed the amount of insurance maintained. Uninsured losses and other expenses, to the extent not recoverable from insurers or the nuclear industry, could also be borne by Generation. Any such losses could have a material adverse effect on Exelon’s and Generation’s financial statements. Spent Nuclear Fuel Obligation (Exelon and Generation) Under the NWPA, the DOE is responsible for the development of a geologic repository for and the disposal of SNF and high-level radioactive waste. As required by the NWPA, Generation is a party to contracts with the DOE (Standard Contracts) to provide for disposal of SNF from Generation’s nuclear generating stations. In accordance with the NWPA and the Standard Contracts, Generation historically had paid the DOE one mill ( $0.001 ) per kWh of net nuclear generation for the cost of SNF disposal. On November 19, 2013, the D.C. Circuit Court ordered the DOE to submit to Congress a proposal to reduce the current SNF disposal fee to zero, unless and until there is a viable disposal program. On May 9, 2014, the DOE notified Generation that the SNF disposal fee remained in effect through May 15, 2014, after which time the fee was set to zero. As a result, for the years ended December 31, 2018 , 2017 and 2016 , Generation did not incur any expense in SNF disposal fees. Until a new fee structure is in effect, Exelon and Generation will not accrue any further costs related to SNF disposal fees. This fee may be adjusted prospectively to ensure full cost recovery. The NWPA and the Standard Contracts required the DOE to begin taking possession of SNF generated by nuclear generating units by no later than January 31, 1998. The DOE, however, failed to meet that deadline and its performance has been, and is expected to be, delayed significantly. The 2010 Federal budget (which became effective October 1, 2009) eliminated almost all funding for the creation of the Yucca Mountain repository while the Obama Administration devised a new strategy for long-term SNF management. The Blue Ribbon Commission (BRC) on America’s Nuclear Future, appointed by the U.S. Energy Secretary, released a report on January 26, 2012, detailing comprehensive recommendations for creating a safe, long-term solution for managing and disposing of the nation’s SNF and high-level radioactive waste. In early 2013, the DOE issued an updated “Strategy for the Management and Disposal of Used Nuclear Fuel and High-Level Radioactive Waste” in response to the BRC recommendations. This strategy included a consolidated interim storage facility that was planned to be operational in 2025. However, due to continued delays on the part of the DOE, Generation currently assumes the DOE will begin accepting SNF in 2030 and uses that date for purposes of estimating the nuclear decommissioning asset retirement obligations. The SNF acceptance date assumption is based on management’s estimates of the amount of time required for DOE to select a site location and develop the necessary infrastructure for long-term SNF storage. In August 2004, Generation and the DOJ, in close consultation with the DOE, reached a settlement under which the government agreed to reimburse Generation, subject to certain damage limitations based on the extent of the government’s breach, for costs associated with storage of SNF at Generation’s nuclear stations pending the DOE’s fulfillment of its obligations. Generation’s settlement agreement does not include FitzPatrick and FitzPatrick does not currently have a settlement agreement in place. Calvert Cliffs, Ginna and Nine Mile Point each have separate settlement agreements in place with the DOE which were extended during 2017 to provide for the reimbursement of SNF storage costs through December 31, 2019. Generation submits annual reimbursement requests to the DOE for costs associated with the storage of SNF. In all cases, reimbursement requests are made only after costs are incurred and only for costs resulting from DOE delays in accepting the SNF. Under the settlement agreements, Generation has received cumulative cash reimbursements for costs incurred as follows: Total Net (a) Cumulative cash reimbursements (b) $ 1,274 $ 1,100 __________ (a) Total after considering amounts due to co-owners of certain nuclear stations and to the former owner of Oyster Creek. (b) Includes $53 and $49 , respectively, for amounts received since April 1, 2014, for costs incurred under the CENG DOE Settlement Agreements prior to the consolidation of CENG. As of December 31, 2018 and 2017 , the amount of SNF storage costs for which reimbursement has been or will be requested from the DOE under the DOE settlement agreements is as follows: December 31, 2018 December 31, 2017 DOE receivable - current (a) $ 124 $ 94 DOE receivable - noncurrent (b) 15 15 Amounts owed to co-owners (a)(c) (17 ) (11 ) __________ (a) Recorded in Accounts receivable, other. (b) Recorded in Deferred debits and other assets, other (c) Non-CENG amounts owed to co-owners are recorded in Accounts receivable, other. CENG amounts owed to co-owners are recorded in Accounts payable. Represents amounts owed to the co-owners of Peach Bottom, Quad Cities, and Nine Mile Point Unit 2 generating facilities. The Standard Contracts with the DOE also required the payment to the DOE of a one-time fee applicable to nuclear generation through April 6, 1983. The fee related to the former PECO units has been paid. Pursuant to the Standard Contracts, ComEd previously elected to defer payment of the one-time fee of $277 million for its units (which are now part of Generation), with interest to the date of payment, until just prior to the first delivery of SNF to the DOE. The unfunded liabilities for SNF disposal costs, including the one-time fee, were transferred to Generation as part of Exelon’s 2001 corporate restructuring. A prior owner of FitzPatrick also elected to defer payment of the one-time fee of $34 million , with interest to the date of payment, for the FitzPatrick unit. As part of the FitzPatrick acquisition on March 31, 2017, Generation assumed a SNF liability for the DOE one-time fee obligation with interest related to FitzPatrick along with an offsetting asset for the contractual right to reimbursement from NYPA, a prior owner of FitzPatrick, for amounts paid for the FitzPatrick DOE one-time fee obligation. The amounts were recorded at fair value. See Note 4 - Mergers, Acquisitions and Dispositions for additional information on the FitzPatrick acquisition. As of December 31, 2018 and 2017 , the SNF liability for the one-time fee with interest was $1,171 million and $1,147 million , respectively, which is included in Exelon's and Generation's Consolidated Balance Sheets. Interest for Exelon's and Generation's SNF liabilities accrues at the 13-week Treasury Rate. The 13-week Treasury Rate in effect for calculation of the interest accrual at December 31, 2018 was 2.351% for the deferred amount transferred from ComEd and 2.217% for the deferred FitzPatrick amount. The outstanding one-time fee obligations for the Nine Mile Point, Ginna, Oyster Creek and TMI units remain with the former owners. The Clinton and Calvert Cliffs units have no outstanding obligation. See Note 11 — Fair Value of Financial Assets and Liabilities for additional information. Environmental Remediation Matters General (All Registrants). The Registrants’ operations have in the past, and may in the future, require substantial expenditures to comply with environmental laws. Additionally, under Federal and state environmental laws, the Registrants are generally liable for the costs of remediating environmental contamination of property now or formerly owned by them and of property contaminated by hazardous substances generated by them. The Registrants own or lease a number of real estate parcels, including parcels on which their operations or the operations of others may have resulted in contamination by substances that are considered hazardous under environmental laws. In addition, the Registrants are currently involved in a number of proceedings relating to sites where hazardous substances have been deposited and may be subject to additional proceedings in the future. Unless otherwise disclosed, the Registrants cannot reasonably estimate whether they will incur significant liabilities for additional investigation and remediation costs at these or additional sites identified by the Registrants, environmental agencies or others, or whether such costs will be recoverable from third parties, including customers. Additional costs could have a material, unfavorable impact on the Registrants' financial statements. MGP Sites (Exelon and the Utility Registrants). ComEd, PECO, BGE and DPL have identified sites where former MGP or gas purification activities have or may have resulted in actual site contamination. For almost all of these sites, there are additional PRPs that may share responsibility for the ultimate remediation of each location. • ComEd has identified 42 sites, 21 of which have been remediated and approved by the Illinois EPA or the U.S. EPA and 21 that are currently under some degree of active study and/or remediation. ComEd expects the majority of the remediation at these sites to continue through at least 2023. • PECO has identified 26 sites, 17 of which have been remediated in accordance with applicable PA DEP regulatory requirements and 9 that are currently under some degree of active study and/or remediation. PECO expects the majority of the remediation at these sites to continue through at least 2022. • BGE has identified 13 sites, 9 of which have been remediated and approved by the MDE and 4 that require some level of remediation and/or ongoing activity. BGE expects the majority of the remediation at these sites to continue through at least 2019. • DPL has identified 3 sites, 2 of which remediation has been completed and approved by the MDE or the Delaware Department of Natural Resources and Environmental Control. The remaining site is under study and the required cost at the site is not expected to be material. The historical nature of the MGP sites and the fact that many of the sites have been buried and built over, impacts the ability to determine a precise estimate of the ultimate costs prior to initial sampling and determination of the exact scope and method of remedial activity. Management determines its best estimate of remediation costs using all available information at the time of each study, including probabilistic and deterministic modeling for ComEd and PECO, and the remediation standards currently required by the applicable state environmental agency. Prior to completion of any significant clean up, each site remediation plan is approved by the appropriate state environmental agency. ComEd, pursuant to an ICC order, and PECO, pursuant to settlements of natural gas distribution rate cases with the PAPUC, are currently recovering environmental remediation costs of former MGP facility sites through customer rates. See Note 4 — Regulatory Matters for additional information regarding the associated regulatory assets. While BGE and DPL do not have riders for MGP clean-up costs, they have historically received recovery of actual clean-up costs in distribution rates. During the third quarter of 2018, the Utility Registrants completed a study of their future estimated environmental remediation requirements. The study resulted in a $48 million increase to the environmental liability and related regulatory asset for ComEd. The increase was primarily due to a revised closure strategy at one site, which resulted in an increase in the excavation area and depth of impacted soils from the site. The study did not result in a material change to the environmental liability for PECO, BGE, Pepco, DPL, and ACE. As of December 31, 2018 and 2017 , the Registrants had accrued the following undiscounted amounts for environmental liabilities in Other current liabilities and Other deferred credits and other liabilities within their respective Consolidated Balance Sheets: December 31, 2018 Total environmental investigation and remediation reserve Portion of total related to MGP investigation and remediation Exelon $ 496 $ 356 Generation 108 — ComEd 329 327 PECO 27 25 BGE 5 4 PHI 27 — Pepco 25 — DPL 1 — ACE 1 — December 31, 2017 Total environmental investigation and remediation reserve Portion of total related to MGP investigation and remediation Exelon $ 466 $ 315 Generation 117 — ComEd 285 283 PECO 30 28 BGE 5 4 PHI 29 — Pepco 27 — DPL 1 — ACE 1 — Cotter Corporation (Exelon and Generation). The EPA has advised Cotter Corporation (Cotter), a former ComEd subsidiary, that it is potentially liable in connection with radiological contamination at a site known as the West Lake Landfill in Missouri. In 2000, ComEd sold Cotter to an unaffiliated third-party. As part of the sale, ComEd agreed to indemnify Cotter for any liability arising in connection with the West Lake Landfill. In connection with Exelon’s 2001 corporate restructuring, this responsibility to indemnify Cotter was transferred to Generation. On May 29, 2008, the EPA issued a Record of Decision (ROD) approving a landfill cover remediation approach. By letter dated January 11, 2010, the EPA requested that the PRPs perform a supplemental feasibility study for a remediation alternative that would involve complete excavation of the radiological contamination. On September 30, 2011, the PRPs submitted the supplemental feasibility study to the EPA for review. Since June 2012, the EPA has requested that the PRPs perform a series of additional analyses and groundwater and soil sampling as part of the supplemental feasibility study. This further analysis was focused on a partial excavation remed |
Supplemental Financial Informat
Supplemental Financial Information (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Supplemental Financial Information [Abstract] | |
Supplemental Financial Information (All Registrants) | Supplemental Financial Information (All Registrants) Supplemental Statement of Operations Information The following tables provide additional information about the Registrants’ Consolidated Statements of Operations and Comprehensive Income for the years ended December 31, 2018 , 2017 and 2016 . For the year ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Taxes other than income Utility (a) $ 919 $ 114 $ 243 $ 131 $ 94 $ 337 $ 316 $ 21 $ — Property 557 273 30 15 143 94 58 32 3 Payroll 247 130 27 16 17 24 5 3 2 Other 60 39 11 1 — — — — — Total taxes other than income $ 1,783 $ 556 $ 311 $ 163 $ 254 $ 455 $ 379 $ 56 $ 5 For the year ended December 31, 2017 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Taxes other than income Utility (a) $ 898 $ 126 $ 240 $ 125 $ 89 $ 318 $ 300 $ 18 $ — Property 545 269 28 14 132 101 62 32 3 Payroll 230 121 26 15 15 26 6 4 2 Other 58 39 2 — 4 7 3 3 1 Total taxes other than income $ 1,731 $ 555 $ 296 $ 154 $ 240 $ 452 $ 371 $ 57 $ 6 Successor Predecessor For the year ended December 31, 2016 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Taxes other than income Utility (a) $ 753 $ 122 $ 242 $ 136 $ 85 $ 312 $ 18 $ — $ 253 $ 78 Property 483 246 27 13 123 53 31 3 73 18 Payroll 226 117 28 15 17 8 5 3 23 8 Other 114 21 (4 ) — 4 4 1 1 5 1 Total taxes other than income $ 1,576 $ 506 $ 293 $ 164 $ 229 $ 377 $ 55 $ 7 $ 354 $ 105 __________ (a) Generation’s utility tax represents gross receipts tax related to its retail operations and ComEd’s, PECO’s, BGE’s, Pepco's, DPL's and ACE's utility taxes represent municipal and state utility taxes and gross receipts taxes related to their operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. For the year ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Other, Net Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 506 $ 506 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 302 302 — — — — — — — Net unrealized losses on NDT funds Regulatory agreement units (715 ) (715 ) — — — — — — — Non-regulatory agreement units (483 ) (483 ) — — — — — — — Net unrealized losses on pledged assets Zion Station decommissioning (8 ) (8 ) — — — — — — — Regulatory offset to NDT fund-related activities (b) 171 171 — — — — — — — Total decommissioning-related activities (227 ) (227 ) — — — — — — — Investment income 43 32 — 1 1 4 2 1 — Interest income related to uncertain income tax positions 5 1 — — — — — — — AFUDC—Equity 69 — 19 7 18 25 22 2 1 Non-service net periodic benefit cost (47 ) — — — — — — — — Other 45 16 14 — — 14 7 7 1 Other, net $ (112 ) $ (178 ) $ 33 $ 8 $ 19 $ 43 $ 31 $ 10 $ 2 For the year ended December 31, 2017 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Other, Net Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 488 $ 488 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 209 209 — — — — — — — Net unrealized gains on NDT funds Regulatory agreement units 455 455 — — — — — — — Non-regulatory agreement units 521 521 — — — — — — — Net unrealized losses on pledged assets Zion Station decommissioning (10 ) (10 ) — — — — — — — Regulatory offset to NDT fund-related activities (b) (724 ) (724 ) — — — — — — — Total decommissioning-related activities 939 939 — — — — — — — Investment income 8 6 — — — 2 1 — — Interest income (expense) related to uncertain income tax positions 3 (1 ) — — — — — — — Benefit related to uncertain income tax positions (c) 2 — — — — — — — — AFUDC—Equity 73 — 12 9 16 36 23 7 6 Non-service net periodic benefit cost (109 ) — — — — — — — — Other 31 4 10 — — 16 8 7 1 Other, net $ 947 $ 948 $ 22 $ 9 $ 16 $ 54 $ 32 $ 14 $ 7 Successor Predecessor For the year ended December 31, 2016 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Other, Net Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 237 $ 237 $ — $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 126 126 — — — — — — — — Net unrealized gains on NDT funds Regulatory agreement units 216 216 — — — — — — — — Non-regulatory agreement units 194 194 — — — — — — — — Net unrealized losses on pledged assets Zion Station decommissioning (1 ) (1 ) — — — — — — — — Regulatory offset to NDT fund-related activities (b) (372 ) (372 ) — — — — — — — — Total decommissioning-related activities 400 400 — — — — — — — — Investment income (loss) 17 8 — (1 ) 2 1 — 1 1 — Long-term lease income 4 — — — — — — — — — Interest income (expense) related to uncertain income tax positions 13 — — — — 1 — — (1 ) — Penalty related to uncertain income tax positions (c) (106 ) — (86 ) — — — — — — — AFUDC—Equity 64 — 14 8 19 19 5 6 23 7 Non-service net periodic benefit cost (116 ) — — — — — — — — — Loss on debt extinguishment (3 ) (2 ) — — — — — — — — Other 24 (5 ) 7 1 — 15 8 2 21 (11 ) Other, net $ 297 $ 401 $ (65 ) $ 8 $ 21 $ 36 $ 13 $ 9 $ 44 $ (4 ) __________ (a) Includes investment income and realized gains and losses on sales of investments within the NDT funds. (b) Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of net income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning. (c) See Note 14 — Income Taxes for additional information on the penalty related to the Tax Court’s decision on Exelon’s like-kind exchange tax position. Supplemental Cash Flow Information The following tables provide additional information regarding the Registrants’ Consolidated Statements of Cash Flows for the years ended December 31, 2018 , 2017 and 2016 . For the year ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Depreciation, amortization and accretion Property, plant and equipment $ 3,740 $ 1,748 $ 820 $ 274 $ 335 $ 480 $ 218 $ 131 $ 94 Regulatory assets 555 — 120 27 148 260 167 51 42 Amortization of intangible assets, net 58 49 — — — — — — — Amortization of energy contract assets and liabilities (a) 14 14 — — — — — — — Nuclear fuel (b) 1,115 1,115 — — — — — — — ARO accretion (c) 489 489 — — — — — — — Total depreciation, amortization and accretion $ 5,971 $ 3,415 $ 940 $ 301 $ 483 $ 740 $ 385 $ 182 $ 136 For the year ended December 31, 2017 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Depreciation, amortization and accretion Property, plant and equipment $ 3,293 $ 1,409 $ 777 $ 261 $ 312 $ 457 $ 203 $ 124 $ 89 Regulatory assets 478 — 73 25 161 218 118 43 57 Amortization of intangible assets, net 57 48 — — — — — — — Amortization of energy contract assets and liabilities (a) 35 35 — — — — — — — Nuclear fuel (b) 1,096 1,096 — — — — — — — ARO accretion (c) 468 468 — — — — — — — Total depreciation, amortization and accretion $ 5,427 $ 3,056 $ 850 $ 286 $ 473 $ 675 $ 321 $ 167 $ 146 Successor Predecessor For the year ended December 31, 2016 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Depreciation, amortization and accretion Property, plant and equipment $ 3,477 $ 1,835 $ 708 $ 244 $ 299 $ 175 $ 110 $ 82 $ 325 $ 94 Regulatory assets 407 — 67 26 124 120 47 83 190 58 Amortization of intangible assets, net 52 44 — — — — — — — — Amortization of energy contract assets and liabilities (a) 35 35 — — — — — — — — Nuclear fuel (b) 1,159 1,159 — — — — — — — — ARO accretion (c) 446 446 — — — — — — — — Total depreciation, amortization and accretion $ 5,576 $ 3,519 $ 775 $ 270 $ 423 $ 295 $ 157 $ 165 $ 515 $ 152 __________ (a) Included in Operating revenues or Purchased power and fuel in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. (b) Included in Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. (c) Included in Operating and maintenance expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. For the year ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Cash paid (refunded) during the year: Interest (net of amount capitalized) $ 1,421 $ 369 $ 332 $ 125 $ 94 $ 250 $ 123 $ 56 $ 61 Income taxes (net of refunds) 95 746 (153 ) (2 ) 14 (32 ) 41 (6 ) (12 ) Other non-cash operating activities: Pension and non-pension postretirement benefit costs $ 583 $ 204 $ 177 $ 18 $ 59 $ 67 $ 15 $ 6 $ 12 Loss (gain) from equity method investments 28 30 — — — (1 ) — — — Provision for uncollectible accounts 159 48 40 33 10 28 11 6 11 Provision for excess and obsolete inventory 24 20 3 — — — — — — Stock-based compensation costs 75 — — — — — — — — Other decommissioning-related activity (a) (2 ) (2 ) — — — — — — — Energy-related options (b) 10 10 — — — — — — — Amortization of regulatory asset related to debt costs 8 — 3 1 — 4 2 1 1 Amortization of rate stabilization deferral 14 — — — — 14 14 — — Amortization of debt fair value adjustment (15 ) (12 ) — — — (3 ) — — — Merger-related commitments (c) — — — — — 5 — 5 — Severance costs 35 9 — — — — — — — Asset retirement costs 20 — — — — 20 22 (1 ) (1 ) Amortization of debt costs 36 14 5 2 1 3 2 — 1 Discrete impacts from EIMA and FEJA (d) 28 — 28 — — — — — — Long-term incentive plan 140 — — — — — — — — Other (19 ) (23 ) (14 ) (3 ) (12 ) 6 (6 ) 7 — Total other non-cash operating activities $ 1,124 $ 298 $ 242 $ 51 $ 58 $ 143 $ 60 $ 24 $ 24 Non-cash investing and financing activities: Change in capital expenditures not paid $ (69 ) $ (199 ) $ 11 $ (12 ) $ 50 $ 93 $ 20 $ 22 $ 46 Change in PPE related to ARO update (107 ) (130 ) 7 — 1 15 12 2 1 Dividends on stock compensation 6 — — — — — — — — Acquisition of land 3 — — — — 3 — — 3 __________ (a) Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning. (b) Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations. (c) See Note 5 - Mergers, Acquisitions and Dispositions for additional information. (d) Reflects the change in ComEd's distribution and energy efficiency formula rates. See Note 4 — Regulatory Matters for additional information. For the year ended December 31, 2017 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Cash paid (refunded) during the year: Interest (net of amount capitalized) $ 2,430 $ 391 $ 307 $ 103 $ 96 $ 236 $ 114 $ 49 $ 59 Income taxes (net of refunds) 540 337 83 47 (2 ) (144 ) (104 ) (49 ) (2 ) Other non-cash operating activities: Pension and non-pension postretirement benefit costs $ 643 $ 227 $ 176 $ 29 $ 62 $ 94 $ 25 $ 13 $ 13 Loss (gain) from equity method investments 32 33 — — — (1 ) — — — Provision for uncollectible accounts 125 38 34 26 8 19 8 3 8 Provision for excess and obsolete inventory 56 51 3 — — 2 1 1 — Stock-based compensation costs 88 — — — — — — — — Other decommissioning-related activity (a) (313 ) (313 ) — — — — — — — Energy-related options (b) 7 7 — — — — — — — Amortization of regulatory asset related to debt costs 9 — 4 1 — 4 2 1 1 Amortization of rate stabilization deferral (10 ) — — — 7 (17 ) (17 ) — — Amortization of debt fair value adjustment (18 ) (12 ) — — — (6 ) — — — Merger-related commitments (c) — — — — — (8 ) (6 ) (2 ) — Severance costs 35 31 — — — 3 — — — Amortization of debt costs 64 37 5 2 2 4 2 — 1 Discrete impacts from EIMA and FEJA (d) (52 ) — (52 ) — — — — — — Vacation accrual adjustment (e) (68 ) (35 ) (12 ) — — (8 ) (8 ) — — Long-term incentive plan 109 — — — — — — — — Change in environmental liabilities 44 44 — — — — — — — Other (30 ) 4 6 (4 ) (14 ) (28 ) (13 ) (7 ) (6 ) Total other non-cash operating activities $ 721 $ 112 $ 164 $ 54 $ 65 $ 58 $ (6 ) $ 9 $ 17 Non-cash investing and financing activities: Change in capital expenditures not paid $ 42 $ 73 $ (61 ) $ 22 $ 23 $ (12 ) $ 5 $ 4 $ (13 ) Change in PPE related to ARO update 29 29 — — — — — — — Non-cash financing of capital projects 16 16 — — — — — — — Indemnification of like-kind exchange position (f) — — 21 — — — — — — Dividends on stock compensation 7 — — — — — — — — Dissolution of financing trust due to long-term debt retirement 8 — — — 8 — — — — Fair value adjustment of long-term debt due to retirement (5 ) — — — — — — — — Fair value of pension and OPEB obligation transferred in connection with FitzPatrick — 33 — — — — — — — __________ (a) Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning. (b) Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations. (c) See Note 5 - Mergers, Acquisitions and Dispositions for additional information. (d) Reflects the change in ComEd's distribution and energy efficiency formula rates . See Note 4 — Regulatory Matters for additional information. (e) On December 1, 2017, Exelon adopted a single, standard vacation accrual policy for all non-represented, non-craft (represented and craft policies remained unchanged) employees effective January 1, 2018. To reflect the new policy, Exelon recorded a one-time, $68 million pre-tax credit to expense to reverse 2018 vacation cost originally accrued throughout 2017 that will now be accrued ratably over the year in 2018. (f) See Note 14 — Income Taxes for additional information on the like-kind exchange tax position. Successor Predecessor For the year ended December 31, 2016 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Cash paid (refunded) during the year: Interest (net of amount capitalized) $ 1,340 $ 339 $ 298 $ 104 $ 92 $ 118 $ 47 $ 62 $ 209 $ 43 Income taxes (net of refunds) (441 ) 435 (444 ) 64 31 216 115 200 258 11 Other non-cash operating activities: Pension and non-pension postretirement benefit costs $ 619 $ 218 $ 166 $ 33 $ 67 $ 31 $ 18 $ 15 $ 86 $ 23 Loss from equity method investments 24 25 — — — — — — — — Provision for uncollectible accounts 155 19 41 30 1 29 23 32 65 16 Stock-based compensation costs 111 — — — — — — — — 3 Other decommissioning-related activity (a) (384 ) (384 ) — — — — — — — — Energy-related options (b) (11 ) (11 ) — — — — — — — — Amortization of regulatory asset related to debt costs 9 — 4 1 — 2 1 1 3 1 Amortization of rate stabilization deferral 76 — — — 81 (12 ) 2 — (5 ) 5 Amortization of debt fair value adjustment (11 ) (11 ) — — — — — — — — Merger-related commitments (c)(d) 558 53 — — — 125 82 110 317 — Severance costs 99 22 — — — — — — 56 — Discrete impacts from EIMA (e) 8 — 8 — — — — — — — Amortization of debt costs 35 17 4 3 1 — — — 1 — Provision for excess and obsolete inventory 12 6 4 — — 3 1 1 1 1 Lower of cost or market inventory adjustment 37 36 — 1 — — — — — — Baltimore City Conduit Lease Settlement (28 ) — — — (28 ) — — — — — Cash Working Capital Order (13 ) — — — (13 ) — — — — — Asset retirement costs 2 — — — — — 1 2 2 — Long-term incentive plan 70 — — — — — — — — — Other (35 ) 25 (12 ) (3 ) (21 ) (3 ) (14 ) (6 ) (11 ) (3 ) Total other non-cash operating activities $ 1,333 $ 15 $ 215 $ 65 $ 88 $ 175 $ 114 $ 155 $ 515 $ 46 Non-cash investing and financing activities: Change in capital expenditures not paid $ (128 ) $ 50 $ (91 ) $ (11 ) $ (86 ) $ 27 $ (12 ) $ 11 $ 21 $ 11 Change in PPE related to ARO update 191 191 — — — — — — — — Indemnification of like-kind exchange position (g) — — 158 — — — — — — — Dividends on stock compensation 6 — — — — — — — — — Non-cash financing of capital projects 95 95 — — — — — — — — Sale of Upstream assets (c) 37 37 — — — — — — — — Pending FitzPatrick Acquisition (h) (54 ) (54 ) — — — — — — — — Fair value of net assets contributed to Generation in connection with the PHI merger, net of cash — 119 — — — — — — — — Fair value of net assets distributed to Exelon in connection with the PHI Merger, net of cash (c)(f) — — — — — — — — 127 — Fair value of pension obligation transferred in connection with the PHI Merger, net of cash (c)(f) — — — — — — — — 53 — Assumption of member purchase liability — — — — — — — — 29 — Assumption of merger commitment liability — — — — — 33 — — 33 — __________ (a) Includes the elimination of NDT fund activity for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning. (b) Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations. (c) See Note 5 - Mergers, Acquisitions and Dispositions for additional information. (d) Excludes $5 million of forgiveness of Accounts receivable related to merger commitments recorded in connection with the PHI Merger, the balance is included within Provision for uncollectible accounts. (e) Reflects the change in distribution rates pursuant to EIMA, which allows for the recovery of costs by a utility through a pre-established performance-based formula rate. See Note 4 — Regulatory Matters for additional information. (f) Immediately following closing of the PHI Merger, the net assets associated with PHI’s unregulated business interests were distributed by PHI to Exelon. Exelon contributed a portion of such net assets to Generation. (g) See Note 14 — Income Taxes for additional information on the like-kind exchange tax position. (h) Reflects the transfer of nuclear fuel to Entergy under the cost reimbursement provisions of the FitzPatrick acquisition agreements. See Note 5 - Mergers, Acquisitions and Dispositions for additional information. The following tables provide a reconciliation of cash, cash equivalents and restricted cash reported within the Registrants' Consolidated Balance Sheets that sum to the total of the same amounts in their Consolidated Statements of Cash Flows. Successor December 31, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Cash and cash equivalents $ 1,349 $ 750 $ 135 $ 130 $ 7 $ 124 $ 16 $ 23 $ 7 Restricted cash 247 153 29 5 6 43 37 1 4 Restricted cash included in other long-term assets 185 — 166 — — 19 — — 19 Total cash, cash equivalents and restricted cash $ 1,781 $ 903 $ 330 $ 135 $ 13 $ 186 $ 53 $ 24 $ 30 Successor December 31, 2017 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Cash and cash equivalents $ 898 $ 416 $ 76 $ 271 $ 17 $ 30 $ 5 $ 2 $ 2 Restricted cash 207 138 5 4 1 42 35 — 6 Restricted cash included in other long-term assets 85 — 63 — — 23 — — 23 Total cash, cash equivalents and restricted cash $ 1,190 $ 554 $ 144 $ 275 $ 18 $ 95 $ 40 $ 2 $ 31 Successor Predecessor December 31, 2016 December 31, 2016 March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Cash and cash equivalents $ 635 $ 290 $ 56 $ 63 $ 23 $ 9 $ 46 $ 101 $ 170 $ 319 Restricted cash 253 158 2 4 24 33 — 9 43 11 Restricted cash included in other long-term assets 26 — — — 3 — — 23 23 18 Total cash, cash equivalents and restricted cash $ 914 $ 448 $ 58 $ 67 $ 50 $ 42 $ 46 $ 133 $ 236 $ 348 Predecessor December 31, 2015 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Cash and cash equivalents $ 6,502 $ 431 $ 67 $ 295 $ 9 $ 26 $ 5 $ 5 $ 3 Restricted cash 205 123 2 3 24 14 2 — 12 Restricted cash included in other long-term assets 5 2 — — 3 18 — — 18 Total cash, cash equivalents and restricted cash $ 6,712 $ 556 $ 69 $ 298 $ 36 $ 58 $ 7 $ 5 $ 33 Supplemental Balance Sheet Information The following tables provide additional information about assets and liabilities of the Registrants at December 31, 2018 and 2017 . December 31, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Unbilled customer revenues (a) $ 1,656 $ 965 $ 223 $ 114 $ 168 $ 186 $ 97 $ 59 $ 30 Allowance for uncollectible accounts (b) (319 ) (104 ) (81 ) (61 ) (20 ) (53 ) (21 ) (13 ) (19 ) December 31, 2017 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Unbilled customer revenues (a) $ 1,858 $ 1,017 $ 242 $ 162 $ 205 $ 232 $ 133 $ 68 $ 31 Allowance for uncollectible (b) (322 ) (114 ) (73 ) (56 ) (24 ) (55 ) (21 ) (16 ) (18 ) __________ (a) Represents unbilled portion of receivables estimated under Exelon’s unbilled critical accounting policy. (b) Includes the estimated allowance for uncollectible accounts on billed customer and other accounts receivable. The Utility Registrants are required, under separate legislation and regulations in Illinois, Pennsylvania, Maryland, District of Columbia and New Jersey, to purchase certain receivables from alternative retail electric and, as applicable, natural gas suppliers that participate in the utilities' consolidated billing. ComEd, BGE, Pepco and DPL purchase receivables at a discount to recover primarily uncollectible accounts expense from the suppliers. PECO and ACE purchase receivables at face value and recover uncollectible accounts expense, including those from alternative retail electric and natural gas supplies, through base distribution rates and a rate rider, respectively. Exelon and the Utility Registrants do not record unbilled commodity receivables under their POR programs. Purchased billed receivables are recorded on a net basis in Exelon’s and the Utility Registrant's Consolidated Statements of Operations and Comprehensive Income and are classified in Other accounts receivable, net in their Consolidated Balance Sheets. The following tables provide information about the purchased receivables of those companies as of December 31, 2018 and 2017 . December 31, 2018 Exelon ComEd PECO BGE PHI Pepco DPL ACE Purchased receivables $ 313 $ 94 $ 74 $ 61 $ 84 $ 57 $ 8 $ 19 Allowance for uncollectible accounts (a) (34 ) (17 ) (5 ) (3 ) (9 ) (5 ) (1 ) (3 ) Purchased receivables, net $ 279 $ 77 $ 69 $ 58 $ 75 $ 52 $ 7 $ 16 December 31, 2017 Exelon ComEd PECO BGE PHI Pepco DPL ACE Purchased receivables $ 298 $ 87 $ 70 $ 58 $ 83 $ 56 $ 9 $ 18 Allowance for uncollectible accounts (a) (31 ) (14 ) (5 ) (3 ) (9 ) (5 ) (1 ) (3 ) Purchased receivables, net $ 267 $ 73 $ 65 $ 55 $ 74 $ 51 $ 8 $ 15 __________ (a) For ComEd, BGE, Pepco and DPL, reflects the incremental allowance for uncollectible accounts recorded, which is in addition to the purchase discount. For ComEd, the incremental uncollectible accounts expense is recovered through a rate rider. BGE, Pepco and DPL recover actual write-offs which are reflected in the POR discount rate. The following tables provide additional information about Registrants' investments at December 31, 2018 and 2017 . December 31, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Investments Equity method investments: Financing trusts (a) $ 14 $ — $ 6 $ 8 $ — $ — $ — $ — $ — Bloom 180 180 — — — — — — — NET Power 70 70 — — — — — — — Other equity method investments 3 1 — — — — — — — Total equity method investments 267 251 6 8 — — — — — Other investments: Employee benefit trusts and investments (b) 244 49 — 17 5 130 105 — — Equity investments without readily determinable fair values 72 72 — — — — — — — Other available for sale debt security investments 40 40 — — — — — — — Other 2 2 — — — — — — — Total investments $ 625 $ 414 $ 6 $ 25 $ 5 $ 130 $ 105 $ — $ — December 31, 2017 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Investments Equity method investments: Financing trusts (a) $ 14 $ — $ 6 $ 8 $ — $ — $ — $ — $ — Bloom 206 206 — — — — — — — NET Power 76 76 — — — — — — — Other equity method investments 1 1 — — — — — — — Total equity method investments 297 283 6 8 — — — — — Other investments: Employee benefit trusts and investments (b) 244 51 — 17 5 132 102 — — Equity investments without readily determinable fair values 62 62 — — — — — — — Other available for sale debt security investments 37 37 — — — — — — — Total investments $ 640 $ 433 $ 6 $ 25 $ 5 $ 132 $ 102 $ — $ — __________ (a) Includes investments in affiliated financing trusts, which were not consolidated within the financial statements of Exelon and are shown as investments in the Consolidated Balance Sheets. See Note 1 — Significant Accounting Policies for additional information. (b) The Registrants’ debt and equity security investments are recorded at fair market value. The following tables provide additional information about liabilities of the Registrants at December 31, 2018 and 2017 . December 31, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Accrued expenses Compensation-related accruals (a) $ 1,191 $ 479 $ 187 $ 49 $ 68 $ 99 $ 29 $ 19 $ 12 Taxes accrued 412 226 71 28 46 74 58 4 5 Interest accrued 334 77 105 33 39 50 25 8 12 Severance accrued 44 26 2 — — 5 — — — Other accrued expenses 131 90 8 3 2 28 14 8 6 Total accrued expenses $ 2,112 $ 898 $ 373 $ 113 $ 155 $ 256 $ 126 $ 39 $ 35 December 31, 2017 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Accrued expenses Compensation-related accruals (a) $ 978 $ 407 $ 158 $ 64 $ 58 $ 106 $ 29 $ 17 $ 11 Taxes accrued 373 444 60 15 71 61 68 4 5 Interest accrued 328 78 102 33 34 48 23 8 12 Severance accrued 58 30 2 — — 17 — — — Other accrued expenses 100 63 5 2 1 29 17 6 5 Total accrued expenses $ 1,837 $ 1,022 $ 327 $ 114 $ 164 $ 261 $ 137 $ 35 $ 33 __________ (a) Primarily includes accrued payroll, bonuses and other incentives, vacation and benefits. |
Segment Information (All Regist
Segment Information (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Segment Reporting [Abstract] | |
Segment Information (All Registrants) | Segment Information (All Registrants) Operating segments for each of the Registrants are determined based on information used by the chief operating decision maker(s) (CODM) in deciding how to evaluate performance and allocate resources at each of the Registrants. Exelon has twelve reportable segments, which include Generation's six reportable segments consisting of the Mid-Atlantic, Midwest, New England, New York, ERCOT and all other power regions referred to collectively as “Other Power Regions” and ComEd, PECO, BGE, PHI's three reportable segments consisting of Pepco, DPL, and ACE. ComEd, PECO, BGE, Pepco, DPL and ACE each represent a single reportable segment, and as such, no separate segment information is provided for these Registrants. Exelon, ComEd, PECO, BGE, Pepco, DPL and ACE's CODMs evaluate the performance of and allocate resources to ComEd, PECO, BGE, Pepco, DPL and ACE based on net income. The basis for Generation's reportable segments is the integrated management of its electricity business that is located in different geographic regions, and largely representative of the footprints of ISO/RTO and/or NERC regions, which utilize multiple supply sources to provide electricity through various distribution channels (wholesale and retail). Generation's hedging strategies and risk metrics are also aligned to these same geographic regions. Descriptions of each of Generation’s six reportable segments are as follows: • Mid-Atlantic represents operations in the eastern half of PJM, which includes New Jersey, Maryland, Virginia, West Virginia, Delaware, the District of Columbia and parts of Pennsylvania and North Carolina. • Midwest represents operations in the western half of PJM and the United States footprint of MISO, excluding MISO’s Southern Region. • New England represents operations within ISO-NE. • New York represents operations within ISO-NY. • ERCOT represents operations within Electric Reliability Council of Texas. • Other Power Regions : • South represents operations in the FRCC, MISO’s Southern Region, the remaining portions of the SERC not included within MISO or PJM. • West represents operations in the WECC, including California ISO. • Canada represents operations across the entire country of Canada and includes AESO, OIESO and the Canadian portion of MISO. The CODMs for Exelon and Generation evaluate the performance of Generation’s electric business activities and allocate resources based on RNF. Generation believes that RNF is a useful measurement of operational performance. RNF is not a presentation defined under GAAP and may not be comparable to other companies’ presentations or deemed more useful than the GAAP information provided elsewhere in this report. Generation’s operating revenues include all sales to third parties and affiliated sales to the Utility Registrants. Purchased power costs include all costs associated with the procurement and supply of electricity including capacity, energy and ancillary services. Fuel expense includes the fuel costs for Generation’s owned generation and fuel costs associated with tolling agreements. The results of Generation's other business activities are not regularly reviewed by the CODM and are therefore not classified as operating segments or included in the regional reportable segment amounts. These activities include natural gas, as well as other miscellaneous business activities that are not significant to Generation's overall operating revenues or results of operations. Further, Generation’s unrealized mark-to-market gains and losses on economic hedging activities and its amortization of certain intangible assets and liabilities relating to commodity contracts recorded at fair value from mergers and acquisitions are also excluded from the regional reportable segment amounts. Exelon and Generation do not use a measure of total assets in making decisions regarding allocating resources to or assessing the performance of these reportable segments. During the first quarter of 2019, due to a change in economics in our New England region, Generation is changing the way that information is reviewed by the CODM. The New England region will no longer be regularly reviewed as a separate region by the CODM nor will it be presented separately in any external information presented to third parties. Information for the New England region will be reviewed by the CODM as part of Other Power Regions. As a result, beginning in the first quarter of 2019, Generation will disclose five reportable segments consisting of Mid-Atlantic, Midwest, New York, ERCOT and Other Power Regions. Beginning in the first quarter of 2019, Other Power Regions will include: • South represents operations in the FRCC, MISO’s Southern Region, the remaining portions of the SERC not included within MISO or PJM. • West represents operations in the WECC, including California ISO. • Canada represents operations across the entire country of Canada and includes AESO, OIESO and the Canadian portion of MISO. • New England represents operations within ISO-NE. An analysis and reconciliation of the Registrants’ reportable segment information to the respective information in the consolidated financial statements for the years ended December 31, 2018 , 2017 , and 2016 is as follows: Successor Generation (a) ComEd PECO BGE PHI (e) Other (b) Intersegment Exelon Operating revenues (c) : 2018 Competitive businesses electric revenues $ 17,411 $ — $ — $ — $ — $ — $ (1,256 ) $ 16,155 Competitive businesses natural gas revenues 2,718 — — — — — (8 ) 2,710 Competitive businesses other revenues 308 — — — — — (5 ) 303 Rate-regulated electric revenues — 5,882 2,470 2,428 4,609 — (45 ) 15,344 Rate-regulated natural gas revenues — — 568 741 181 — (20 ) 1,470 Shared service and other revenues — — — — 15 1,948 (1,960 ) 3 Total operating revenues $ 20,437 $ 5,882 $ 3,038 $ 3,169 $ 4,805 $ 1,948 $ (3,294 ) $ 35,985 2017 Competitive businesses electric revenues $ 15,332 $ — $ — $ — $ — $ — $ (1,105 ) $ 14,227 Competitive businesses natural gas revenues 2,575 — — — — — — 2,575 Competitive businesses other revenues 593 — — — — — (1 ) 592 Rate-regulated electric revenues — 5,536 2,375 2,489 4,469 — (29 ) 14,840 Rate-regulated natural gas revenues — — 495 687 161 — (10 ) 1,333 Shared service and other revenues — — — — 49 1,831 (1,880 ) — Total operating revenues $ 18,500 $ 5,536 $ 2,870 $ 3,176 $ 4,679 $ 1,831 $ (3,025 ) $ 33,567 Successor Generation (a) ComEd PECO BGE PHI (e) Other (b) Intersegment Exelon 2016 Competitive businesses electric revenues $ 15,400 $ — $ — $ — $ — $ — $ (1,430 ) $ 13,970 Competitive businesses natural gas revenues 2,146 — — — — — — 2,146 Competitive businesses other revenues 211 — — — — — (4 ) 207 Rate-regulated electric revenues — 5,254 2,531 2,609 3,506 — (31 ) 13,869 Rate-regulated natural gas revenues — — 463 624 92 — (13 ) 1,166 Shared service and other revenues — — — — 45 1,648 (1,686 ) 7 Total operating revenues $ 17,757 $ 5,254 $ 2,994 $ 3,233 $ 3,643 $ 1,648 $ (3,164 ) $ 31,365 Intersegment revenues (d) : 2018 $ 1,269 $ 27 $ 8 $ 29 $ 15 $ 1,942 $ (3,289 ) $ 1 2017 1,110 15 7 16 50 1,824 (3,020 ) 2 2016 1,428 15 8 21 45 1,647 (3,159 ) 5 Depreciation and amortization: 2018 $ 1,797 $ 940 $ 301 $ 483 $ 740 $ 92 $ — $ 4,353 2017 1,457 850 286 473 675 87 — 3,828 2016 1,879 775 270 423 515 74 — 3,936 Operating expenses (c) : 2018 $ 19,510 $ 4,741 $ 2,452 $ 2,696 $ 4,156 $ 1,929 $ (3,341 ) $ 32,143 2017 18,001 4,214 2,215 2,562 3,911 1,742 (3,026 ) 29,619 2016 16,878 4,056 2,292 2,683 3,549 1,812 (3,164 ) 28,106 Interest expense, net: 2018 $ 432 $ 347 $ 129 $ 106 $ 261 $ 279 $ — $ 1,554 2017 440 361 126 105 245 283 — 1,560 2016 364 461 123 103 195 290 — 1,536 Income (loss) before income taxes: 2018 $ 365 $ 832 $ 466 $ 387 $ 432 $ (249 ) $ (1 ) $ 2,232 2017 1,455 984 538 525 578 (296 ) (2 ) 3,782 2016 857 679 587 468 (58 ) (555 ) (5 ) 1,973 Income taxes: 2018 $ (108 ) $ 168 $ 6 $ 74 $ 35 $ (55 ) $ — $ 120 2017 (1,376 ) 417 104 218 217 294 — (126 ) 2016 282 301 149 174 3 (156 ) — 753 Successor Generation (a) ComEd PECO BGE PHI (e) Other (b) Intersegment Exelon Net income (loss): 2018 $ 443 $ 664 $ 460 $ 313 $ 398 $ (193 ) $ (1 ) $ 2,084 2017 2,798 567 434 307 362 (590 ) (2 ) 3,876 2016 550 378 438 294 (61 ) (398 ) (5 ) 1,196 Capital expenditures: 2018 $ 2,242 $ 2,126 $ 849 $ 959 $ 1,375 $ 43 $ — $ 7,594 2017 $ 2,259 $ 2,250 $ 732 $ 882 $ 1,396 $ 65 $ — $ 7,584 2016 $ 3,078 $ 2,734 $ 686 $ 934 $ 1,008 $ 113 $ — $ 8,553 Total assets: 2018 $ 47,556 $ 31,213 $ 10,642 $ 9,716 $ 21,984 $ 8,355 $ (9,800 ) $ 119,666 2017 48,457 29,726 10,170 9,104 21,247 8,618 (10,552 ) 116,770 __________ (a) See Note 25 — Related Party Transactions for additional information on intersegment revenues. (b) Other primarily includes Exelon’s corporate operations, shared service entities and other financing and investment activities. (c) Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 23 — Supplemental Financial Information for additional information on total utility taxes. (d) Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory authoritative guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. (e) Amounts included represent activity for PHI's successor period, March 24, 2016 through December 31, 2018 . Successor and Predecessor PHI: Pepco DPL ACE Other (b) Intersegment PHI Operating revenues (a) : December 31, 2018 - Successor Rate-regulated electric revenues $ 2,239 $ 1,151 $ 1,236 $ — $ (17 ) $ 4,609 Rate-regulated natural gas revenues — 181 — — — 181 Shared service and other revenues — — — 435 (420 ) 15 Total operating revenues $ 2,239 $ 1,332 $ 1,236 $ 435 $ (437 ) $ 4,805 December 31, 2017 - Successor Rate-regulated electric revenues $ 2,158 $ 1,139 $ 1,186 $ — $ (14 ) $ 4,469 Rate-regulated natural gas revenues — 161 — — — 161 Shared service and other revenues — — — 52 (3 ) 49 Total operating revenues $ 2,158 $ 1,300 $ 1,186 $ 52 $ (17 ) $ 4,679 March 24, 2016 to December 31, 2016 - Successor Rate-regulated electric revenues $ 1,675 $ 850 $ 989 $ 5 $ (13 ) $ 3,506 Rate-regulated natural gas revenues — 92 — — — 92 Shared service and other revenues — — — 45 — 45 Total operating revenues $ 1,675 $ 942 $ 989 $ 50 $ (13 ) $ 3,643 January 1, 2016 to March 23, 2016 - Predecessor Rate-regulated electric revenues $ 511 $ 279 $ 268 $ 42 $ (4 ) $ 1,096 Rate-regulated natural gas revenues — 56 — 1 — 57 Shared service and other revenues — — — — — — Total operating revenues $ 511 $ 335 $ 268 $ 43 $ (4 ) $ 1,153 Intersegment revenues: December 31, 2018 - Successor $ 6 $ 8 $ 3 $ 435 $ (437 ) $ 15 December 31, 2017 - Successor 6 8 2 53 (19 ) 50 March 24, 2016 to December 31, 2016 - Successor 4 5 2 47 (13 ) 45 January 1, 2016 to March 23, 2016 - Predecessor 1 2 1 — (4 ) — Depreciation and amortization: December 31, 2018 - Successor $ 385 $ 182 $ 136 $ 37 $ — $ 740 December 31, 2017 - Successor 321 167 146 42 (1 ) $ 675 March 24, 2016 to December 31, 2016 - Successor 224 120 128 43 — $ 515 January 1, 2016 to March 23, 2016 - Predecessor 71 37 37 11 (4 ) $ 152 Operating expenses: December 31, 2018 - Successor $ 1,919 $ 1,143 $ 1,087 $ 442 $ (435 ) $ 4,156 December 31, 2017 - Successor 1,760 1,071 1,029 68 (17 ) $ 3,911 March 24, 2016 to December 31, 2016 - Successor 1,577 952 1,000 33 (13 ) $ 3,549 January 1, 2016 to March 23, 2016 - Predecessor 443 284 251 73 (3 ) $ 1,048 Pepco DPL ACE Other (b) Intersegment PHI Interest expense, net: December 31, 2018 - Successor $ 128 $ 58 $ 64 $ 11 $ — $ 261 December 31, 2017 - Successor 121 51 61 13 (1 ) $ 245 March 24, 2016 to December 31, 2016 - Successor 98 38 47 12 — $ 195 January 1, 2016 to March 23, 2016 - Predecessor 29 12 15 11 (2 ) $ 65 Income (loss) before income taxes: December 31, 2018 - Successor $ 223 $ 142 $ 87 $ 388 $ (408 ) $ 432 December 31, 2017 - Successor 310 192 103 377 (404 ) $ 578 March 24, 2016 to December 31, 2016 - Successor 36 (30 ) (51 ) (84 ) 71 $ (58 ) January 1, 2016 to March 23, 2016 - Predecessor 47 43 5 59 (118 ) $ 36 Income taxes: December 31, 2018 - Successor $ 13 $ 22 $ 12 $ (10 ) $ (2 ) $ 35 December 31, 2017 - Successor 105 71 26 15 — $ 217 March 24, 2016 to December 31, 2016 - Successor 26 5 (5 ) (23 ) — $ 3 January 1, 2016 to March 23, 2016 - Predecessor 15 17 1 (16 ) — $ 17 Net income (loss): December 31, 2018 - Successor $ 210 $ 120 $ 75 $ (22 ) $ 15 $ 398 December 31, 2017 - Successor 205 121 77 (91 ) 50 $ 362 March 24, 2016 to December 31, 2016 - Successor 10 (35 ) (47 ) (34 ) 45 $ (61 ) January 1, 2016 to March 23, 2016 - Predecessor 32 26 5 (44 ) — $ 19 Capital expenditures: December 31, 2018 - Successor $ 656 $ 364 $ 335 $ 20 $ — $ 1,375 December 31, 2017 - Successor 628 428 312 28 — $ 1,396 March 24, 2016 to December 31, 2016 - Successor 489 277 218 24 — 1,008 January 1, 2016 to March 23, 2016 - Predecessor 97 72 93 11 — 273 Total assets: December 31, 2018 - Successor $ 8,299 $ 4,588 $ 3,699 $ 10,819 $ (5,421 ) $ 21,984 December 31, 2017 - Successor 7,832 4,357 3,445 10,600 (4,987 ) 21,247 __________ (a) Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 23 — Supplemental Financial Information for additional information on total utility taxes. (b) Other primarily includes PHI’s corporate operations, shared service entities and other financing and investment activities. For the predecessor periods presented, Other includes the activity of PHI’s unregulated businesses which were distributed to Exelon and Generation as a result of the PHI Merger. The following tables disaggregate the Registrants' revenue recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. For Generation, the disaggregation of revenues reflects Generation's two primary products of power sales and natural gas sales, with further disaggregation of power sales provided by geographic region. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of rate-regulated electric sales and rate-regulated natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon's disaggregated revenues are consistent with Generation and the Utility Registrants but exclude any intercompany revenues. Competitive Business Revenues (Generation): 2018 Revenues from external customers (a) Contracts with customers Other (b) Total Intersegment Revenues Total Revenues Mid-Atlantic $ 5,241 $ 233 $ 5,474 $ 13 $ 5,487 Midwest 4,527 190 4,717 (11 ) 4,706 New England 2,660 185 2,845 (4 ) 2,841 New York 1,723 (36 ) 1,687 — 1,687 ERCOT 572 560 1,132 1 1,133 Other Power Regions 870 686 1,556 (62 ) 1,494 Total Competitive Businesses Electric Revenues 15,593 1,818 17,411 (63 ) 17,348 Competitive Businesses Natural Gas Revenues 1,524 1,194 2,718 62 2,780 Competitive Businesses Other Revenues (c) 510 (202 ) 308 1 309 Total Generation Consolidated Operating Revenues 17,627 2,810 $ 20,437 $ — $ 20,437 2017 Revenues from external customers (a) Contracts with customers Other (b) Total Intersegment Revenues Total Revenues Mid-Atlantic $ 5,523 $ (8 ) $ 5,515 $ 25 $ 5,540 Midwest 3,923 283 4,206 (25 ) 4,181 New England 2,064 (54 ) 2,010 (8 ) 2,002 New York 1,605 (38 ) 1,567 (17 ) 1,550 ERCOT 641 317 958 4 962 Other Power Regions 594 482 1,076 (27 ) 1,049 Total Competitive Businesses Electric Revenues 14,350 982 15,332 (48 ) 15,284 Competitive Businesses Natural Gas Revenues 1,658 917 2,575 53 2,628 Competitive Businesses Other Revenues (c) 744 (151 ) 593 (5 ) 588 Total Generation Consolidated Operating Revenues $ 16,752 $ 1,748 $ 18,500 $ — $ 18,500 2016 Revenues from external customers (a) Contracts with customers Other (b) Total Intersegment Revenues Total Revenues Mid-Atlantic $ 6,182 $ 30 $ 6,212 $ (33 ) $ 6,179 Midwest 4,007 395 4,402 10 4,412 New England 1,953 (175 ) 1,778 (9 ) 1,769 New York 1,198 10 1,208 (42 ) 1,166 ERCOT 810 21 831 6 837 Other Power Regions 670 299 969 (62 ) 907 Total Competitive Businesses Electric Revenues 14,820 580 15,400 (130 ) 15,270 Competitive Businesses Natural Gas Revenues 1,953 193 2,146 135 2,281 Competitive Businesses Other Revenues (c) 756 (545 ) 211 (5 ) 206 Total Generation Consolidated Operating Revenues $ 17,529 $ 228 $ 17,757 $ — $ 17,757 __________ (a) Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants. (b) Includes revenues from derivatives and leases. (c) Other represents activities not allocated to a region. See text above for a description of included activities. Includes a $38 million and $52 million decrease to revenues for the amortization of intangible assets and liabilities related to commodity contracts recorded at fair value in 2017 and 2016 , respectively, unrealized mark-to-market losses of $262 million , $131 million , and $500 million in 2018 , 2017 , and 2016 , respectively, and elimination of intersegment revenues. Revenues net of purchased power and fuel expense (Generation): 2018 2017 2016 RNF from external (a) Intersegment Total RNF RNF from external (a) Intersegment RNF Total RNF RNF from external (a) Intersegment Total RNF Mid-Atlantic $ 3,022 $ 51 $ 3,073 $ 3,105 $ 109 $ 3,214 $ 3,282 $ 35 $ 3,317 Midwest 3,112 23 3,135 2,810 10 2,820 2,969 2 2,971 New England 368 (14 ) 354 538 (24 ) 514 467 (29 ) 438 New York 1,112 10 1,122 1,007 1 1,008 771 (19 ) 752 ERCOT 501 (243 ) 258 575 (243 ) 332 412 (131 ) 281 Other Power Regions 515 (140 ) 375 476 (171 ) 305 483 (147 ) 336 Total Revenues net of purchased power and fuel for Reportable Segments $ 8,630 $ (313 ) $ 8,317 $ 8,511 $ (318 ) $ 8,193 $ 8,384 $ (289 ) $ 8,095 Other (b) 114 313 427 299 318 617 543 289 832 Total Generation Revenues net of purchased power and fuel expense $ 8,744 $ — $ 8,744 $ 8,810 $ — $ 8,810 $ 8,927 $ — $ 8,927 __________ (a) Includes purchases and sales from/to third parties and affiliated sales to the Utility Registrants. (b) Other represents activities not allocated to a region. See text above for a description of included activities. Includes a $54 million and $57 million decrease in RNF for the amortization of intangible assets and liabilities related to commodity contracts in 2017 and 2016 , respectively, unrealized mark-to-market losses of $319 million , $175 million , and $41 million in 2018 , 2017 , and 2016 , respectively, accelerated nuclear fuel amortization associated with the announced early plant retirements as discussed in Note 8 - Early Plant Retirements of $57 million , $12 million and $60 million for the year ended December 31, 2018 , 2017 , and 2016 and the elimination of intersegment RNF. Electric and Gas Revenue by Customer Class (Utility Registrants): 2018 Successor Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 2,942 $ 1,566 $ 1,382 $ 2,351 $ 1,021 $ 669 $ 661 Small commercial & industrial 1,487 404 257 488 140 186 162 Large commercial & industrial 538 223 429 1,124 846 100 178 Public authorities & electric railroads 47 28 28 58 32 14 12 Other (a) 867 243 327 593 193 175 227 Total rate-regulated electric revenues (b) 5,881 2,464 2,423 4,614 2,232 1,144 1,240 Rate-regulated natural gas revenues Residential — 395 491 99 — 99 — Small commercial & industrial — 143 77 44 — 44 — Large commercial & industrial — 1 124 8 — 8 — Transportation — 23 — 16 — 16 — Other (c) — 6 63 13 — 13 — Total rate-regulated natural gas revenues (d) — 568 755 180 — 180 — Total rate-regulated revenues from contracts with customers 5,881 3,032 3,178 4,794 2,232 1,324 1,240 Other revenues Revenues from alternative revenue programs (29 ) (7 ) (26 ) — — 4 (4 ) Other rate-regulated electric revenues (e) 30 12 13 10 7 3 — Other rate-regulated natural gas revenues (e) — 1 4 1 — 1 — Total other revenues 1 6 (9 ) 11 7 8 (4 ) Total rate-regulated revenues for reportable segments $ 5,882 $ 3,038 $ 3,169 $ 4,805 $ 2,239 $ 1,332 $ 1,236 2017 Successor Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 2,715 $ 1,505 $ 1,365 $ 2,246 $ 964 $ 663 $ 619 Small commercial & industrial 1,363 401 254 490 137 187 166 Large commercial & industrial 455 223 427 1,086 794 103 189 Public authorities & electric railroads 44 30 31 60 33 14 13 Other (a) 886 204 299 541 199 163 191 Total rate-regulated electric revenues (b) 5,463 2,363 2,376 4,423 2,127 1,130 1,178 Rate-regulated natural gas revenues Residential — 331 437 90 — 90 — Small commercial & industrial — 131 75 38 — 38 — Large commercial & industrial — 1 119 8 — 8 — Transportation — 23 — 15 — 15 — Other (c) — 8 28 9 — 9 — Total rate-regulated natural gas revenues (d) — 494 659 160 — 160 — Total rate-regulated revenues from contracts with customers 5,463 2,857 3,035 4,583 2,127 1,290 1,178 Other revenues Revenues from alternative revenue programs 43 — 124 40 26 6 8 Other rate-regulated electric revenues (e) 30 12 13 8 5 3 — Other rate-regulated natural gas revenues (e) — 1 4 1 — 1 — Other revenues (f) — — — 47 — — — Total other revenues 73 13 141 96 31 10 8 Total rate-regulated revenues for reportable segments $ 5,536 $ 2,870 $ 3,176 $ 4,679 $ 2,158 $ 1,300 $ 1,186 Successor Predecessor 2016 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Revenues from contracts with customers ComEd PECO BGE Pepco DPL ACE PHI PHI Rate-regulated electric revenues Residential $ 2,603 $ 1,631 $ 1,504 $ 1,004 $ 672 $ 664 $ 1,779 $ 561 Small commercial & industrial 1,318 430 276 150 188 183 400 121 Large commercial & industrial 462 234 434 790 99 201 835 255 Public authorities & electric railroads 45 32 35 32 13 13 45 13 Other (a) 820 192 276 190 160 187 400 169 Total rate-regulated electric revenues (b) 5,248 2,519 2,525 2,166 1,132 1,248 3,459 1,119 Rate-regulated natural gas revenues Residential — 309 432 — 86 — 50 36 Small commercial & industrial — 121 66 — 35 — 21 14 Large commercial & industrial — — 114 — 6 — 4 2 Transportation — 24 — — 13 — 10 3 Other (c) — 9 28 — 8 — 7 2 Total rate-regulated natural gas revenues (d) — 463 640 — 148 — 92 57 Total rate-regulated revenues from contracts with customers 5,248 2,982 3,165 2,166 1,280 1,248 3,551 1,176 Other revenues Revenues from alternative revenue programs (24 ) — 53 14 (6 ) 9 43 (26 ) Other rate-regulated electric revenues (e) 30 12 13 6 3 — 6 3 Other rate-regulated natural gas revenues (e) — — 2 — — — — — Other revenues (f) — — — — — — 43 — Total other revenues 6 12 68 20 (3 ) 9 92 (23 ) Total rate-regulated revenues for reportable segments $ 5,254 $ 2,994 $ 3,233 $ 2,186 $ 1,277 $ 1,257 $ 3,643 $ 1,153 __________ (a) Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue. (b) Includes operating revenues from affiliates of $ 27 million , $7 million , $8 million , $15 million , $6 million , $8 million and $3 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2018 , $15 million , $6 million , $5 million , $3 million , $6 million , $8 million and $2 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, in 2017 , and $15 million , $7 million , $7 million , $2 million , $5 million , $7 million and $3 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2016 . (c) Includes revenues from off-system natural gas sales. (d) Includes operating revenues from affiliates of $1 million and $21 million at PECO and BGE, respectively, in 2018 , $1 million and $11 million at PECO and BGE, respectively, in 2017 , and $1 million and $14 million at PECO and BGE, respectively, in 2016 . (e) Includes late payment charge revenues. (f) Includes operating revenues from affiliates of $47 million and $43 million at PHI in 2017 and 2016 , respectively. |
Related Party Transactions (All
Related Party Transactions (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Related Party Transactions [Abstract] | |
Related-Party Transactions (All Registrants) | (All Registrants) Exelon The financial statements of Exelon include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: Generation (a) (2 ) — PECO (a) — 1 1 BGE (a) — 4 4 ACE (a) — — — Other 1 2 5 Total operating revenues from affiliates $ (1 ) $ 7 $ 10 Interest expense to affiliates, net: ComEd Financing III $ 13 $ 14 $ 13 PECO Trust III 6 6 6 PECO Trust IV 6 6 6 BGE Capital Trust II — 10 16 Total interest expense to affiliates, net $ 25 $ 36 $ 41 Earnings (losses) in equity method investments: Qualifying facilities and domestic power projects $ (29 ) $ (33 ) $ (25 ) Other 1 1 1 Total losses in equity method investments $ (28 ) $ (32 ) $ (24 ) December 31, 2018 2017 Payables to affiliates (current): ComEd Financing III $ 4 $ 4 PECO Trust III 1 1 Total payables to affiliates (current) $ 5 $ 5 Long-term debt to financing trusts: ComEd Financing III $ 206 $ 205 PECO Trust III 81 81 PECO Trust IV 103 103 Total long-term debt to financing trusts $ 390 $ 389 __________ (a) The intersegment profit associated with the sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory authoritative guidance. For Exelon, these amounts are included in operating revenues in the Consolidated Statements of Operations. See Note 4 — Regulatory Matters for additional information. Transactions involving Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE are further described in the tables below. Generation The financial statements of Generation include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: ComEd (a) $ 523 $ 121 $ 47 PECO (b) 128 138 290 BGE (c) 260 388 608 Pepco (d) 206 255 295 DPL (e) 120 179 154 ACE (f) 29 29 37 BSC 2 1 2 Other — 4 6 Total operating revenues from affiliates $ 1,268 $ 1,115 $ 1,439 Purchased power and fuel from affiliates: ComEd $ (6 ) $ 13 $ — BGE 20 9 12 Other — (3 ) — Total purchased power and fuel from affiliates $ 14 $ 19 $ 12 Operating and maintenance from affiliates: ComEd (g) $ 7 $ 7 $ 7 PECO (g) 2 1 3 BGE (g) 2 1 1 Pepco 1 — 1 PHISCO 1 1 1 BSC (h) 652 689 650 Other (4 ) (2 ) — Total operating and maintenance from affiliates $ 661 $ 697 $ 663 Interest expense to affiliates, net: Exelon Corporate (i) $ 36 $ 37 $ 39 PCI — 1 — PECO — 1 — Total interest expense to affiliates, net: $ 36 $ 39 $ 39 Earnings (losses) in equity method investments Qualifying facilities and domestic power projects $ (30 ) $ (33 ) $ (25 ) Capitalized costs BSC (h) $ 67 $ 98 $ 98 Cash distributions paid to member $ 1,001 $ 659 $ 922 Contributions from member $ 155 $ 102 $ 142 December 31, 2018 2017 Receivables from affiliates (current): ComEd (a) $ 69 $ 28 PECO (b) 30 26 BGE (c) 24 24 Pepco (d) 28 36 DPL (e) 7 12 ACE (f) 5 6 PHISCO (h) — 1 Other 10 7 Total receivables from affiliates (current) $ 173 $ 140 Intercompany money pool (current): Exelon Corporate $ 100 $ — PCI — 54 Total intercompany money pool (current) $ 100 $ 54 Payables to affiliates (current): Exelon Corporate (i) $ 17 $ 21 BSC (h) 95 74 ComEd 19 12 PECO (b) — 4 Other 8 12 Total payables to affiliates (current) $ 139 $ 123 Other liabilities to affiliates (current): ComEd (a) $ 14 $ — Long-term debt to affiliates (noncurrent): Exelon Corporate (k) $ 898 $ 910 Payables to affiliates (noncurrent): ComEd (j) $ 2,217 $ 2,528 PECO (j) 389 537 Total payables to affiliates (noncurrent) $ 2,606 $ 3,065 __________ (a) Generation has an ICC-approved RFP contract with ComEd to provide a portion of ComEd’s electricity supply requirements. Generation also sells RECs and ZECs to ComEd. (b) Generation provides electric supply to PECO under contracts executed through PECO’s competitive procurement process. In addition, Generation has a ten-year agreement with PECO to sell solar AECs. (c) Generation provides a portion of BGE’s energy requirements under its MDPSC-approved market-based SOS and gas commodity programs. (d) Generation provides electric supply to Pepco under contracts executed through Pepco's competitive procurement process approved by the MDPSC and DCPSC. (e) Generation provides a portion of DPL's energy requirements under its MDPSC and DPSC approved market based SOS and gas commodity programs. (f) Generation provides electric supply to ACE under contracts executed through ACE's competitive procurement process. (g) Generation requires electricity for its own use at its generating stations. Generation purchases electricity and distribution and transmission services from PECO and BGE and only distribution and transmission services from ComEd for the delivery of electricity to its generating stations. (h) Generation receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (i) The balance consists of interest owed to Exelon Corporation related to the senior unsecured notes, as well as, expense related to certain invoices Exelon Corporation processed on behalf of Generation. (j) Generation has long-term payables to ComEd and PECO as a result of the nuclear decommissioning contractual construct whereby, to the extent NDT funds are greater than the underlying ARO at the end of decommissioning, such amounts are due back to ComEd and PECO, as applicable, for payment to their respective customers. See Note 15 — Asset Retirement Obligations for additional information. (k) In connection with the debt obligations assumed by Exelon as part of the Constellation merger, Exelon and subsidiaries of Generation (former Constellation subsidiaries) assumed intercompany loan agreements that mirror the terms and amounts of the third-party debt obligations of Exelon, resulting in intercompany notes payable included in Long-term Debt to affiliates in Generation’s Consolidated Balance Sheets and intercompany notes receivable at Exelon Corporate, which are eliminated in consolidation in Exelon’s Consolidated Balance Sheets. ComEd The financial statements of ComEd include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates Generation $ 9 $ 9 $ 7 BSC 7 6 6 PECO 10 — 1 BGE 1 — 1 Total operating revenues from affiliates $ 27 $ 15 $ 15 Purchased power from affiliates Generation (a) $ 529 $ 108 $ 47 Operating and maintenance from affiliates BSC (b) $ 265 $ 270 $ 225 PECO 1 — 1 BGE 1 — 1 Total operating and maintenance from affiliates $ 267 $ 270 $ 227 Interest expense to affiliates, net: ComEd Financing III $ 13 $ 13 $ 13 Capitalized costs BSC (b) $ 135 $ 118 $ 112 Cash dividends paid to parent $ 459 $ 422 $ 369 Contributions from parent $ 500 $ 651 $ 315 December 31, 2018 2017 Prepaid voluntary employee beneficiary association trust (c) $ 5 $ 2 Receivables from affiliates (current): Voluntary employee beneficiary association trust $ 1 $ 1 Generation 19 12 Total receivables from affiliates (current) $ 20 $ 13 Receivables from affiliates (noncurrent): Generation (d) $ 2,217 $ 2,528 Payables to affiliates (current): Generation (a) $ 55 $ 28 BSC (b) 56 39 ComEd Financing III 4 4 Exelon Corporate 4 3 Total payables to affiliates (current) $ 119 $ 74 Long-term debt to ComEd financing trust: ComEd Financing III $ 205 $ 205 __________ (a) ComEd procures a portion of its electricity supply requirements from Generation under an ICC-approved RFP contract. ComEd also purchases RECs and ZECs from Generation. (b) ComEd receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (c) The voluntary employee benefit association trusts covering active employees are included in corporate operations and are funded by the Registrants. A prepayment to the active welfare plans has accumulated due to actuarially determined contribution rates, which are the basis for ComEd’s contributions to the plans, being higher than actual claim expense incurred by the plans over time. The prepayment is included in other current assets. (d) ComEd has a long-term receivable from Generation as a result of the nuclear decommissioning contractual construct for generating facilities previously owned by ComEd. To the extent the assets associated with decommissioning are greater than the applicable ARO at the end of decommissioning, such amounts are due back to ComEd for payment to ComEd’s customers. PECO The financial statements of PECO include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: Generation (a) $ 2 $ 1 $ 3 BSC 3 5 3 ComEd 1 — 1 BGE 1 1 1 ACE 1 — — Total operating revenues from affiliates $ 8 $ 7 $ 8 Purchased power from affiliates Generation (b) $ 126 $ 135 $ 287 Operating and maintenance from affiliates: BSC (c) $ 146 $ 146 $ 142 Generation 2 2 2 ComEd 7 — 1 BGE 1 1 1 Total operating and maintenance from affiliates $ 156 $ 149 $ 146 Interest expense to affiliates, net: PECO Trust III $ 6 $ 6 $ 6 PECO Trust IV 6 6 6 Exelon Corporate 2 — — Generation — (1 ) — Total interest expense to affiliates, net: $ 14 $ 11 $ 12 Capitalized costs BSC (c) $ 64 $ 59 $ 57 Cash dividends paid to parent $ 306 $ 288 $ 277 Contributions from parent $ 89 $ 16 $ 18 December 31, 2018 2017 Prepaid voluntary employee beneficiary association trust (d) $ 1 $ — Receivables from affiliates (noncurrent): Generation (e) $ 389 $ 537 Payables to affiliates (current): Generation (b) $ 30 $ 22 BSC (c) 26 29 Exelon Corporate 2 1 PECO Trust III 1 1 Total payables to affiliates (current) $ 59 $ 53 Long-term debt to financing trusts: PECO Trust III $ 81 $ 81 PECO Trust IV 103 103 Total long-term debt to financing trusts $ 184 $ 184 __________ (a) PECO provides energy to Generation for Generation’s own use. (b) PECO purchases electric supply from Generation under contracts executed through its competitive procurement process. In addition, PECO has five-year and ten-year agreements with Generation to purchase non-solar and solar AECs, respectively. (c) PECO receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (d) The voluntary employee beneficiary association trusts covering active employees are included in corporate operations and are funded by the Registrants. A prepayment to the active welfare plans has accumulated due to actuarially determined contribution rates, which are the basis for PECO’s contributions to the plans, being higher than actual claim expense incurred by the plans over time. (e) PECO has a long-term receivable from Generation as a result of the nuclear decommissioning contractual construct, whereby, to the extent the assets associated with decommissioning are greater than the applicable ARO at the end of decommissioning, such amounts are due back to PECO for payment to PECO’s customers. BGE The financial statements of BGE include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: Generation (a) $ 22 $ 10 $ 13 BSC 5 5 6 ComEd 1 — 1 PECO 1 1 1 Total operating revenues from affiliates $ 29 $ 16 $ 21 Purchased power from affiliates Generation (b) $ 257 $ 384 $ 604 Operating and maintenance from affiliates: BSC (c) $ 157 $ 152 $ 130 Generation 3 — — ComEd 1 — 1 PECO 1 1 1 Total operating and maintenance from affiliates $ 162 $ 153 $ 132 Interest expense to affiliates, net: BGE Capital Trust II $ — $ 10 $ 16 Capitalized costs BSC (c) $ 79 $ 54 $ 36 Cash dividends paid to parent $ 209 $ 198 $ 179 Contributions from parent $ 109 $ 184 $ 61 December 31, 2018 2017 Receivables from affiliates (current): Other $ 1 $ 1 Payables to affiliates (current): Generation (b) $ 24 $ 24 BSC (c) 38 25 Exelon Corporate 2 1 Other 1 2 Total payables to affiliates (current) $ 65 $ 52 __________ (a) BGE provides energy to Generation for Generation’s own use. (b) BGE procures a portion of its electricity and gas supply requirements from Generation under its MDPSC-approved market-based SOS and gas commodity programs. (c) BGE receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. PHI The financial statements of PHI include related party transactions as presented in the tables below: Successor For the Year Ended December 31, For the Year Ended December 31, March 24, 2016 to December 31, 2018 2017 2016 Operating revenues from affiliates: BSC $ 12 $ 48 $ 44 PHISCO 1 2 — Generation 2 — 1 Total operating revenues from affiliates $ 15 $ 50 $ 45 Purchased power from affiliates Generation $ 355 $ 463 $ 486 Operating and maintenance from affiliates: BSC (a) $ 147 $ 145 $ 86 Other 5 5 3 Total operating and maintenance from affiliates $ 152 $ 150 $ 89 Earnings (losses) in equity method investments: Other $ 1 $ — $ — Capitalized costs: BSC (a) $ 102 $ — $ — PHISCO (a) 79 — — Total capitalized costs $ 181 $ — $ — Cash dividends paid to parent $ 326 $ 311 $ 273 Contributions from parent $ 385 $ 758 $ 1,251 December 31, 2018 2017 Payables to affiliates (current): Generation $ 40 $ 54 BGE — 1 BSC (a) 41 24 Exelon Corporate 6 6 Other 7 5 Total payables to affiliates (current) $ 94 $ 90 __________ (a) PHI receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. Pepco The financial statements of Pepco include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: Generation (a) $ 1 $ — $ 1 BSC 1 — — PHISCO 4 6 4 Total operating revenues from affiliates $ 6 $ 6 $ 5 Purchased power from affiliates Generation (b) $ 206 $ 255 $ 295 Operating and maintenance: PHISCO (c), (e) $ — $ 219 $ 263 PES (d) — 29 39 Total operating and maintenance $ — $ 248 $ 302 Operating and maintenance from affiliates: BSC (c) $ 89 $ 53 $ 31 PHISCO (c), (e) 137 5 4 Total operating and maintenance from affiliates $ 226 $ 58 $ 35 Capitalized costs: BSC (c) $ 40 $ — $ — PHISCO (c) 32 — — Total capitalized costs $ 72 $ — $ — Cash dividends paid to parent $ 169 $ 133 $ 136 Contributions from parent $ 166 $ 161 $ 187 December 31, 2018 2017 Receivables from affiliates (current): DPL $ 1 $ — Payables to affiliates (current): Exelon Corporation $ 1 $ — Generation (b) 28 36 BSC (c) 19 11 PHISCO (c) 14 27 Total payables to affiliates (current) $ 62 $ 74 __________ (a) Pepco provides energy to Generation for Generation’s own use. (b) Pepco procures a portion of its electricity supply requirements from Generation under its MDPSC and DCPSC approved market based SOS commodity programs. (c) Pepco receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (d) PES performed underground transmission, distribution construction and maintenance services, including services that are treated as capital costs, for Pepco. (e) Due to the PHI entities' system conversion to Exelon's accounting systems on January 1, 2018, corporate support services received from PHISCO are reported in Operating and maintenance from affiliates in 2018. DPL The financial statements of DPL include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: BSC $ 1 $ — $ — PHISCO 4 6 5 ComEd 1 — — ACE 1 — — Other 1 2 2 Total operating revenues from affiliates $ 8 $ 8 $ 7 Purchased power from affiliates Generation (a) $ 120 $ 179 $ 154 Operating and maintenance: PHISCO (b), (d) $ — $ 165 $ 194 PES (c) — 9 8 Total operating and maintenance $ — $ 174 $ 202 Operating and maintenance from affiliates: BSC (b) $ 51 $ 31 $ 18 PHISCO (b), (d) 111 — — Other — 1 1 Total operating and maintenance from affiliates $ 162 $ 32 $ 19 Capitalized costs: BSC (b) $ 28 $ — $ — PHISCO (b) 25 — — Total capitalized costs $ 53 $ — $ — Cash dividends paid to parent $ 96 $ 112 $ 54 Contributions from parent $ 150 $ — $ 152 December 31, 2018 2017 Payables to affiliates (current): Exelon Corporate $ 1 $ — Generation (a) 7 12 BSC (b) 11 7 PHISCO (b) 12 27 Pepco 1 — ACE 1 — Total payables to affiliates (current) $ 33 $ 46 __________ (a) DPL procures a portion of its electricity and gas supply requirements from Generation under its MDPSC and DPSC approved market based SOS and gas commodity programs. (b) DPL receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (c) PES performed underground transmission construction services, including services that are treated as capital costs, for DPL. (d) Due to the PHI entities' system conversion to Exelon's accounting systems on January 1, 2018, corporate support services received from PHISCO are reported in Operating and maintenance from affiliates in 2018. ACE The financial statements of ACE include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: PHISCO $ 2 $ 1 $ 2 Other 1 1 1 Total operating revenues from affiliates $ 3 $ 2 $ 3 Purchased power from affiliates Generation (a) $ 29 $ 29 $ 37 Operating and maintenance: PHISCO (b), (c) $ — $ 135 $ 155 Operating and maintenance from affiliates: BSC (b) $ 42 $ 25 $ 15 PHISCO (b), (c) 98 — — Other 2 3 3 Total operating and maintenance from affiliates $ 142 $ 28 $ 18 Capitalized costs: BSC (b) $ 20 $ — $ — PHISCO (b) 21 — — Total capitalized costs $ 41 $ — $ — Cash dividends paid to parent $ 59 $ 68 $ 63 Contributions from parent $ 67 $ — $ 139 December 31, 2018 2017 Receivable from affiliate (current): DPL $ 1 $ — Payables to affiliates (current): Generation (a) $ 5 $ 6 BSC (b) 8 5 PHISCO (b) 13 18 Other 2 — Total payables to affiliates (current) $ 28 $ 29 __________ (a) ACE purchases electric supply from Generation under contracts executed through its competitive procurement process. (b) ACE receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (c) Due to the PHI entities' system conversion to Exelon's accounting systems on January 1, 2018, corporate support services received from PHISCO are reported in Operating and maintenance from affiliates in 2018. |
Quarterly Data (Unaudited) (All
Quarterly Data (Unaudited) (All Registrants) | 12 Months Ended |
Dec. 31, 2018 | |
Quarterly Financial Data [Abstract] | |
Quarterly Data (Unaudited) (All Registrants) | Quarterly Data (Unaudited) (All Registrants) Exelon The data shown below, which may not equal the total for the year due to the effects of rounding and dilution, includes all adjustments that Exelon considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 9,693 $ 8,747 $ 1,101 $ 1,308 $ 585 $ 990 June 30 8,076 7,665 942 300 539 95 September 30 9,403 8,768 1,146 1,499 733 823 December 31 8,814 8,384 708 1,288 152 1,880 Net Income Net Income 2018 2017 2018 2017 Quarter ended: March 31 $ 0.61 $ 1.07 $ 0.60 $ 1.06 June 30 0.56 0.10 0.56 0.10 September 30 0.76 0.86 0.76 0.85 December 31 0.16 1.95 0.16 1.94 Generation The data shown below includes all adjustments that Generation considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income (Loss) Net Income (Loss) 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 5,512 $ 4,878 $ 347 $ 373 $ 136 $ 418 June 30 4,579 4,216 282 (427 ) 178 (235 ) September 30 5,278 4,750 311 497 234 304 December 31 5,069 4,657 35 504 (178 ) 2,224 ComEd The data shown below includes all adjustments that ComEd considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 1,512 $ 1,298 $ 292 $ 314 $ 165 $ 141 June 30 1,398 1,357 288 319 164 118 September 30 1,598 1,571 323 404 193 189 December 31 1,373 1,309 242 286 141 120 PECO The data shown below includes all adjustments that PECO considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 866 $ 796 $ 142 $ 192 $ 113 $ 127 June 30 653 630 127 137 96 88 September 30 757 715 154 169 126 112 December 31 765 729 165 157 124 107 BGE The data shown below includes all adjustments that BGE considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 977 $ 951 $ 177 $ 228 $ 128 $ 125 June 30 662 674 85 98 51 45 September 30 731 738 103 124 63 62 December 31 799 813 109 163 71 76 PHI The data shown below includes all adjustments that PHI considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income Attributable to Membership Interest 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 1,251 $ 1,175 $ 126 $ 180 $ 65 $ 140 June 30 1,076 1,074 153 148 84 66 September 30 1,361 1,310 245 285 187 153 December 31 1,117 1,121 126 159 62 4 Pepco The data shown below includes all adjustments that Pepco considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 557 $ 530 $ 56 $ 79 $ 31 $ 58 June 30 523 514 85 84 54 43 September 30 628 604 112 149 89 87 December 31 531 510 65 87 36 17 DPL The data shown below includes all adjustments that DPL considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 384 $ 362 $ 49 $ 78 $ 31 $ 57 June 30 289 282 42 41 26 19 September 30 328 327 51 59 33 31 December 31 331 330 48 52 30 14 ACE The data shown below includes all adjustments that ACE considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income (Loss) 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 310 $ 275 $ 23 $ 25 $ 7 $ 28 June 30 265 270 25 25 8 8 September 30 406 370 84 79 61 41 December 31 254 271 14 28 (1 ) — |
Subsequent Events Subsequent Ev
Subsequent Events Subsequent Events (Exelon and Generation) | 12 Months Ended |
Dec. 31, 2018 | |
Subsequent Events [Abstract] | |
Subsequent Events [Text Block] | Subsequent Events (Exelon and Generation) Generation’s Antelope Valley, a 242 MW solar facility in Lancaster, CA, sells all of its output to Pacific Gas and Electric Company (PG&E) through a PPA. As of December 31, 2018, Generation had approximately $750 million and $510 million of net long-lived assets and nonrecourse debt outstanding, respectively, related to Antelope Valley. The nonrecourse debt is guaranteed by the DOE Loan Programs Office. Neither the guarantor nor the lender have recourse against Exelon or Generation in the event of default. On January 29, 2019, PG&E filed for protection under Chapter 11 of the U.S. Bankruptcy Code. PG&E’s bankruptcy creates an event of default for Antelope Valley’s nonrecourse debt. As such, Antelope Valley is currently in discussions with the DOE Loan Programs Office, and the debt has not yet been accelerated. Given that the event of default did not occur until January 2019, the debt continued to be classified as non-current on Exelon’s and Generation’s Consolidated Balance Sheets as of December 31, 2018, and may be reclassified to current in 2019. Generation has also assessed and determined that Antelope Valley’s long-lived assets are not impaired as of December 31, 2018. Changes in assumptions such as the likelihood of the PPA being rejected as part of the bankruptcy proceedings could potentially result in future impairments of Antelope Valley. The impairment loss could be substantially all of the net long-lived assets if Antelope Valley was valued without the PPA. Generation is monitoring the bankruptcy proceedings for any changes in circumstances that would indicate the carrying amount of the net long-lived assets of Antelope Valley may not be recoverable. Antelope Valley is a wholly owned indirect subsidiary of EGR IV, which had approximately $1,990 million and $830 million of additional net long-lived assets and nonrecourse debt outstanding, respectively, as of December 31, 2018. EGR IV is a wholly owned indirect subsidiary of Exelon and Generation and includes Generation's interest in EGRP and other projects with non-controlling interests. EGR IV is currently not in default, however, an acceleration of Antelope Valley’s debt could impact EGR IV. The lenders do not have recourse against Exelon or Generation in the event of default by EGR IV. See Note 2 - Variable Interest Entities for additional details on EGRP and Note 13 — Debt and Credit Agreements for additional details on Generation's nonrecourse project financings . |
Schedule I - Condensed Financia
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) | 12 Months Ended |
Dec. 31, 2018 | |
Condensed Financial Information of Parent Company Only Disclosure [Abstract] | |
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) | Exelon Corporation and Subsidiary Companies Schedule I – Condensed Financial Information of Parent (Exelon Corporate) Condensed Statements of Operations and Other Comprehensive Income For the Years Ended December 31, (In millions) 2018 2017 2016 Operating expenses Operating and maintenance $ (5 ) $ 10 $ 221 Operating and maintenance from affiliates 9 25 51 Other 4 4 4 Total operating expenses 8 39 276 Operating loss (8 ) (39 ) (276 ) Other income and (deductions) Interest expense, net (312 ) (315 ) (312 ) Equity in earnings of investments 2,188 4,414 1,508 Interest income from affiliates, net 42 40 39 Other, net 3 1 7 Total other income 1,921 4,140 1,242 Income before income taxes 1,913 4,101 966 Income taxes (97 ) 315 (155 ) Net income $ 2,010 $ 3,786 $ 1,121 Other comprehensive income (loss) Pension and non-pension postretirement benefit plans: Prior service benefit reclassified to periodic costs $ (66 ) $ (56 ) $ (48 ) Actuarial loss reclassified to periodic cost 247 197 184 Pension and non-pension postretirement benefit plan valuation adjustment (143 ) 10 (181 ) Unrealized gain on cash flow hedges 12 3 2 Unrealized gain on marketable securities — 6 1 Unrealized gain (loss) on equity investments 1 6 (4 ) Unrealized (loss) gain on foreign currency translation (10 ) 7 10 Other comprehensive income (loss) 41 173 (36 ) Comprehensive income $ 2,051 $ 3,959 $ 1,085 Exelon Corporation and Subsidiary Companies Schedule I – Condensed Financial Information of Parent (Exelon Corporate) Condensed Statements of Cash Flows For the Years Ended December 31, (In millions) 2018 2017 2016 Net cash flows provided by operating activities $ 2,581 $ 1,921 $ 1,029 Cash flows from investing activities Changes in Exelon intercompany money pool 1 (129 ) 1,390 Investment in affiliates (1,236 ) (1,717 ) (1,757 ) Acquisition of business — — (6,962 ) Other investing activities — (5 ) 5 Net cash flows used in investing activities (1,235 ) (1,851 ) (7,324 ) Cash flows from financing activities Issuance of long-term debt — — 1,800 Proceeds from short-term borrowings with maturities greater than 90 days — 500 — Retirement of long-term debt — (569 ) (46 ) Common stock issued from treasury stock — 1,150 — Dividends paid on common stock (1,332 ) (1,236 ) (1,166 ) Proceeds from employee stock plans 105 150 55 Other financing activities (4 ) (9 ) (20 ) Net cash flows (used in) provided by financing activities (1,231 ) (14 ) 623 Increase (Decrease) in cash, cash equivalents and restricted cash 115 56 (5,672 ) Cash, cash equivalents and restricted cash at beginning of period 74 18 5,690 Cash, cash equivalents and restricted cash at end of period $ 189 $ 74 $ 18 Exelon Corporation and Subsidiary Companies Schedule I – Condensed Financial Information of Parent (Exelon Corporate) Condensed Balance Sheets December 31, (In millions) 2018 2017 ASSETS Current assets Cash and cash equivalents $ 189 $ 74 Accounts receivable, net Other accounts receivable 48 431 Accounts receivable from affiliates 44 33 Notes receivable from affiliates 216 217 Regulatory assets 182 284 Other 4 4 Total current assets 683 1,043 Property, plant and equipment, net 48 50 Deferred debits and other assets Regulatory assets 3,742 3,697 Investments in affiliates 40,448 39,311 Deferred income taxes 1,455 1,431 Notes receivable from affiliates 898 910 Other 235 234 Total deferred debits and other assets 46,778 45,583 Total assets $ 47,509 $ 46,676 Exelon Corporation and Subsidiary Companies Schedule I – Condensed Financial Information of Parent (Exelon Corporate) Condensed Balance Sheets December 31, (In millions) 2018 2017 LIABILITIES AND SHAREHOLDERS’ EQUITY Current liabilities Short-term borrowings $ 500 $ 500 Accounts payable 1 2 Accrued expenses 184 99 Payables to affiliates 360 360 Regulatory liabilities 15 16 Pension obligations 63 65 Other 14 46 Total current liabilities 1,137 1,088 Long-term debt 7,147 7,161 Deferred credits and other liabilities Regulatory liabilities 32 15 Pension obligations 7,795 7,792 Non-pension postretirement benefit obligations 199 322 Deferred income taxes 233 220 Other 202 180 Total deferred credits and other liabilities 8,461 8,529 Total liabilities 16,745 16,778 Commitments and contingencies Shareholders’ equity Common stock (No par value, 2,000 shares authorized, 968 shares and 963 shares outstanding at December 31, 2018 and 2017, respectively) 19,116 18,966 Treasury stock, at cost (2 shares at December 31, 2018 and 2017) (123 ) (123 ) Retained earnings 14,766 14,081 Accumulated other comprehensive loss, net (2,995 ) (3,026 ) Total shareholders’ equity 30,764 29,898 Total liabilities and shareholders’ equity $ 47,509 $ 46,676 Basis of Presentation Exelon Corporate is a holding company that conducts substantially all of its business operations through its subsidiaries. These condensed financial statements and related footnotes have been prepared in accordance with Rule 12-04, Schedule I of Regulation S-X. These statements should be read in conjunction with the consolidated financial statements and notes thereto of Exelon Corporation. Exelon Corporate owns 100% of all of its significant subsidiaries, either directly or indirectly, except for Commonwealth Edison Company (ComEd), of which Exelon Corporate owns more than 99% , and BGE, of which Exelon owns 100% of the common stock but none of BGE’s preferred stock. BGE redeemed all of its outstanding preferred stock in 2016. Mergers On March 23, 2016, Exelon completed the merger contemplated by the Merger Agreement among Exelon, Purple Acquisition Corp., a wholly owned subsidiary of Exelon (Merger Sub) and Pepco Holdings, Inc. (PHI). As a result of that merger, Merger Sub was merged into PHI (the PHI Merger) with PHI surviving as a wholly owned subsidiary of Exelon and Exelon Energy Delivery Company, LLC (EEDC), a wholly owned subsidiary of Exelon which also owns Exelon's interests in ComEd, PECO and BGE (through a special purpose subsidiary in the case of BGE). See Note 5 — Mergers, Acquisitions and Dispositions of the Combined Notes to Consolidated Financial Statements for additional information on the PHI Merger. Debt and Credit Agreements Short-Term Borrowings Exelon Corporate meets its short-term liquidity requirements primarily through the issuance of commercial paper. Exelon Corporate had no commercial paper borrowings at both December 31, 2018 and December 31, 2017 . Short-Term Loan Agreements On March 23, 2017, Exelon Corporate entered into a $500 million term loan agreement which expired on March 22, 2018. The loan agreement was renewed on March 22, 2018 and will expire on March 21, 2019. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR plus 1% and all indebtedness thereunder is unsecured. The loan agreement is reflected in Exelon’s Consolidated Balance Sheet within Short-Term borrowings. Credit Agreements On May 26, 2016, Exelon Corporate amended its syndicated revolving credit facility with aggregate bank commitments of $600 million through May 26, 2021. On May 26, 2018, Exelon Corporate had its maturity date extended to May 26, 2023. As of December 31, 2018 , Exelon Corporation had available capacity under those commitments of $591 million . See Note 13 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information regarding Exelon Corporation’s credit agreement. Long-Term Debt The following tables present the outstanding long-term debt for Exelon Corporate as of December 31, 2018 and December 31, 2017 : Maturity Date December 31, Rates 2018 2017 Long-term debt Junior subordinated notes 3.50 % 2022 $ 1,150 $ 1,150 Senior unsecured notes (a) 2.45 % 7.60 % 2020 - 2046 5,889 5,889 Total long-term debt 7,039 7,039 Unamortized debt discount and premium, net (7 ) (8 ) Unamortized debt issuance costs (47 ) (49 ) Fair value adjustment of consolidated subsidiary 162 179 Long-term debt $ 7,147 $ 7,161 __________ (a) Senior unsecured notes include mirror debt that is held on both Generation and Exelon Corporation's balance sheets. The debt maturities for Exelon Corporate for the periods 2019 , 2020 , 2021 , 2022 , 2023 and thereafter are as follows: 2019 $ — 2020 1,450 2021 300 2022 1,150 2023 — Remaining years 4,139 Total long-term debt $ 7,039 Commitments and Contingencies See Note 22 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for Exelon Corporate’s commitments and contingencies related to environmental matters and fund transfer restrictions. Related Party Transactions The financial statements of Exelon Corporate include related party transactions as presented in the tables below: For the Years Ended December 31, (In millions) 2018 2017 2016 Operating and maintenance from affiliates: BSC (a) $ 11 $ 23 $ 51 Other (2 ) 2 — Total operating and maintenance from affiliates: $ 9 $ 25 $ 51 Interest income from affiliates, net: Generation $ 36 $ 37 $ 39 BSC 4 3 — Exelon Energy Delivery Company, LLC (b) $ 2 $ — $ — Total interest income from affiliates, net: $ 42 $ 40 $ 39 Equity in earnings (losses) of investments: Exelon Energy Delivery Company, LLC (b) $ 1,835 $ 1,670 $ 1,041 PCI (17 ) 1 6 BSC — 1 1 UII, LLC — 41 (9 ) Exelon Transmission Company, LLC 1 (10 ) (13 ) Exelon Enterprise — 1 (1 ) Generation 369 2,710 483 Total equity in earnings of investments: $ 2,188 $ 4,414 $ 1,508 Cash contributions received from affiliates $ 2,302 $ 1,879 $ 1,912 December 31, (in millions) 2018 2017 Accounts receivable from affiliates (current): BSC (a) $ 13 $ 1 Generation 17 21 ComEd 4 3 PECO 2 1 BGE 2 1 PHISCO 6 6 Total accounts receivable from affiliates (current): $ 44 $ 33 Notes receivable from affiliates (current): BSC (a) $ 116 $ 217 Generation (c) 100 — Total notes receivable from affiliates (current): $ 216 $ 217 Investments in affiliates: BSC (a) $ 197 $ 196 Exelon Energy Delivery Company, LLC (b) 26,702 25,082 PCI 61 78 UII, LLC 268 268 Exelon Transmission Company, LLC 1 1 Voluntary Employee Beneficiary Association trust (1 ) (4 ) Exelon Enterprises 22 22 Generation 13,204 13,674 Other (6 ) (6 ) Total investments in affiliates: $ 40,448 $ 39,311 Notes receivable from affiliates (non-current): Generation (c) $ 898 $ 910 Accounts payable to affiliates (current): UII, LLC $ 360 $ 360 __________ (a) Exelon Corporate receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. (b) Exelon Energy Delivery Company, LLC consists of ComEd, PECO, BGE, PHI, Pepco, DPL and ACE. (c) In connection with the debt obligations assumed by Exelon as part of the Constellation merger, Exelon and subsidiaries of Generation (former Constellation subsidiaries) assumed intercompany loan agreements that mirror the terms and amounts of the third-party debt obligations of Exelon, resulting in intercompany notes payable included in Long-Term Debt to affiliates in Generation’s Consolidated Balance Sheets and intercompany notes receivable at Exelon Corporate, which are eliminated in consolidation in Exelon’s Consolidated Balance Sheets. |
Schedule II - Valuation and Qua
Schedule II - Valuation and Qualifying Accounts | 12 Months Ended |
Dec. 31, 2018 | |
Valuation and Qualifying Accounts [Abstract] | |
Valuation and Qualifying Accounts | Exelon Corporation and Subsidiary Companies Schedule II – Valuation and Qualifying Accounts Column A Column B Column C Column D Column E Additions and adjustments Description Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions Balance at End of Period (in millions) For the year ended December 31, 2018 Allowance for uncollectible accounts (a) $ 322 $ 159 $ 35 (c) $ 197 (e) $ 319 Deferred tax valuation allowance 37 — 5 7 35 Reserve for obsolete materials 174 25 (31 ) (d) 12 156 For the year ended December 31, 2017 Allowance for uncollectible accounts (a) $ 334 $ 126 $ 27 (c) $ 165 (e) $ 322 Deferred tax valuation allowance 20 — 17 — 37 Reserve for obsolete materials 113 56 10 5 174 For the year ended December 31, 2016 Allowance for uncollectible accounts (a) $ 284 $ 162 $ 99 (b)(c) $ 211 (e) $ 334 Deferred tax valuation allowance 13 — 10 (b) 3 20 Reserve for obsolete materials 105 12 1 (b) 5 113 __________ (a) Excludes the non-current allowance for uncollectible accounts related to PECO’s installment plan receivables of $13 million , $15 million , and $23 million for the years ended December 31, 2018 , 2017 and 2016 , respectively. (b) Primarily represents the addition of PHI's results as of March 23, 2016 , the date of the merger (c) Includes charges for late payments and non-service receivables. (d) Primarily reflects the reclassification of assets as held for sale. (e) Write-off of individual accounts receivable. Exelon Generation Company, LLC and Subsidiary Companies (2) Generation (i) Financial Statements (Item 8): Report of Independent Registered Public Accounting Firm dated February 8, 2019 of PricewaterhouseCoopers LLP Consolidated Statements of Operations and Comprehensive Income for the Years Ended December 31, 2018, 2017 and 2016 Consolidated Statements of Cash Flows for the Years Ended December 31, 2018, 2017 and 2016 Consolidated Balance Sheets at December 31, 2018 and 2017 Consolidated Statements of Changes in Equity for the Years Ended December 31, 2018, 2017 and 2016 Notes to Consolidated Financial Statements (ii) Financial Statement Schedule: Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2018, 2017 and 2016 Schedules not included are omitted because of the absence of conditions under which they are required or because the required information is provided in the consolidated financial statements, including the notes thereto Exelon Generation Company, LLC and Subsidiary Companies Schedule II – Valuation and Qualifying Accounts Column A Column B Column C Column D Column E Additions and adjustments Description Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions Balance at End of Period (in millions) For the year ended December 31, 2018 Allowance for uncollectible accounts $ 114 $ 44 $ 4 $ 58 $ 104 Deferred tax valuation allowance 23 — 3 — 26 Reserve for obsolete materials 166 20 (32 ) (a) 9 145 For the year ended December 31, 2017 Allowance for uncollectible accounts $ 91 $ 34 $ — $ 11 $ 114 Deferred tax valuation allowance 9 — 14 — 23 Reserve for obsolete materials 106 51 9 — 166 For the year ended December 31, 2016 Allowance for uncollectible accounts $ 77 $ 19 $ 3 $ 8 $ 91 Deferred tax valuation allowance 11 — — 2 9 Reserve for obsolete materials 102 6 — 2 106 __________ (a) Primarily reflects the reclassification of assets as held for sale. Commonwealth Edison Company and Subsidiary Companies (3) ComEd (i) Financial Statements (Item 8): Report of Independent Registered Public Accounting Firm dated February 8, 2019 of PricewaterhouseCoopers LLP Consolidated Statements of Operations and Comprehensive Income for the Years Ended December 31, 2018, 2017 and 2016 Consolidated Statements of Cash Flows for the Years Ended December 31, 2018, 2017 and 2016 Consolidated Balance Sheets at December 31, 2018 and 2017 Consolidated Statements of Changes in Shareholders’ Equity for the Years Ended December 31, 2018, 2017 and 2016 Notes to Consolidated Financial Statements (ii) Financial Statement Schedule: Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2018, 2017 and 2016 Schedules not included are omitted because of the absence of conditions under which they are required or because the required information is provided in the consolidated financial statements, including the notes thereto Commonwealth Edison Company and Subsidiary Companies Schedule II – Valuation and Qualifying Accounts Column A Column B Column C Column D Column E Additions and adjustments Description Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions Balance at End of Period (in millions) For the year ended December 31, 2018 Allowance for uncollectible accounts $ 73 $ 44 $ 23 (a) $ 59 (b) $ 81 Reserve for obsolete materials 5 3 1 3 6 For the year ended December 31, 2017 Allowance for uncollectible accounts $ 70 $ 39 $ 20 (a) $ 56 (b) $ 73 Reserve for obsolete materials 4 3 1 3 5 For the year ended December 31, 2016 Allowance for uncollectible accounts $ 75 $ 45 $ 23 (a) $ 73 (b) $ 70 Reserve for obsolete materials 3 4 1 4 4 __________ (a) Primarily charges for late payments and non-service receivables. (b) Write-off of individual accounts receivable. PECO Energy Company and Subsidiary Companies (4) PECO (i) Financial Statements (Item 8): Report of Independent Registered Public Accounting Firm dated February 8, 2019 of PricewaterhouseCoopers LLP Consolidated Statements of Operations and Comprehensive Income for the Years Ended December 31, 2018, 2017 and 2016 Consolidated Statements of Cash Flows for the Years Ended December 31, 2018, 2017 and 2016 Consolidated Balance Sheets at December 31, 2018 and 2017 Consolidated Statements of Changes in Shareholder's Equity for the Years Ended December 31, 2018, 2017 and 2016 Notes to Consolidated Financial Statements (ii) Financial Statement Schedule: Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2018, 2017 and 2016 Schedules not included are omitted because of the absence of conditions under which they are required or because the required information is provided in the consolidated financial statements, including the notes thereto PECO Energy Company and Subsidiary Companies Schedule II – Valuation and Qualifying Accounts Column A Column B Column C Column D Column E Additions and adjustments Description Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions Balance at End of Period (in millions) For the year ended December 31, 2018 Allowance for uncollectible accounts (a) $ 56 $ 33 $ 3 (b) $ 31 (c) $ 61 Reserve for obsolete materials 2 — — — 2 For the year ended December 31, 2017 Allowance for uncollectible accounts (a) $ 61 $ 26 $ 4 (b) $ 35 (c) $ 56 Reserve for obsolete materials 2 — — — 2 For the year ended December 31, 2016 Allowance for uncollectible accounts (a) $ 83 $ 32 $ 7 (b) $ 61 (c) $ 61 Reserve for obsolete materials 1 1 — — 2 __________ (a) Excludes the non-current allowance for uncollectible accounts related to PECO’s installment plan receivables of $13 million , $15 million , and $23 million for the years ended December 31, 2018 , 2017 , and 2016 , respectively. (b) Primarily charges for late payments. (c) Write-off of individual accounts receivable. Baltimore Gas and Electric Company and Subsidiary Companies (5) BGE (i) Financial Statements (Item 8): Report of Independent Registered Public Accounting Firm dated February 8, 2019 of PricewaterhouseCoopers LLP Consolidated Statements of Operations and Comprehensive Income for the Years Ended December 31, 2018, 2017 and 2016 Consolidated Statements of Cash Flows for the Years Ended December 31, 2018, 2017 and 2016 Consolidated Balance Sheets at December 31, 2018 and 2017 Consolidated Statements of Changes in Shareholder's Equity for the Years Ended December 31, 2018, 2017 and 2016 Notes to Consolidated Financial Statements (ii) Financial Statement Schedule: Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2018, 2017 and 2016 Schedules not included are omitted because of the absence of conditions under which they are required or because the required information is provided in the consolidated financial statements, including the notes thereto Baltimore Gas and Electric Company and Subsidiary Companies Schedule II – Valuation and Qualifying Accounts Column A Column B Column C Column D Column E Additions and adjustments Description Balance at Beginning of Period Charged to Costs and Expenses Charged to Other Accounts Deductions Balance at End of Period (in millions) For the year ended December 31, 2018 Allowance for uncollectible accounts $ 24 $ 10 $ (2 ) $ 12 (a) $ 20 Deferred tax valuation allowance 1 — — — 1 Reserve for obsolete materials — 1 — — 1 For the year ended December 31, 2017 Allowance for uncollectible accounts $ 32 $ 8 $ (3 ) $ 13 (a) $ 24 Deferred tax valuation allowance 1 — — — 1 Reserve for obsolete materials — — — — — For the year ended December 31, 2016 Allowance for uncollectible accounts $ 49 $ 1 $ 9 $ 27 (a) $ 32 Deferred tax valuation allowance 1 — — — 1 Reserve for obsolete materials — — — — — __________ (a) Write-off of individual accounts receivable. Pepco Holdings LLC and Subsidiary Companies (6) PHI (i) Successor Company Financial Statements (Item 8): Report of Independent Registered Public Accounting Firm dated February 8, 2019 of PricewaterhouseCoopers LLP Consolidated Statements of Operations and Comprehensive Income (Loss) for the Years Ended December 31, 2018 and 2017 and for the Period March 24, 2016 to December 31, 2016 Consolidated Statements of Cash Flows for the Years Ended December 31, 2018 and 2017 and for the Period March 24, 2016 to December 31, 2016 Consolidated Balance Sheets at December 31, 2018 and 2017 Consolidated Statements of Changes in Equity for the Years Ended December 31, 2018 and 2017 and for the Period March 24, 2016 to December 31, 2016 Notes to Consolidated Financial Statements (ii) Predecessor Company Financial Statements (Item 8): Report of Independent Registered Public Accounting Firm dated February 13, 2017 of PricewaterhouseCoopers LLP Consolidated Statements of Operations and Comprehensive Income for the Period January 1, 2016 to March 23, 2016 Consolidated Statements of Cash Flows for the Period January 1, 2016 to March 23, 2016 Consolidated Statements of Changes in Equity for the Period January 1, 2016 to March 23, 2016 Notes to Consolidated Financial Statements (iii) Successor Financial Statement Schedule: Schedule II – Valuation and Qualifying Accounts - For the Years Ended December 31, 2018 and 2017 and the Period March 24, 2016 to December 31, 2016 (iv) Predecessor Financial Statement Schedule: Schedule II – Valuation and Qualifying Accounts - For the Period January 1, 2016 to March 23, 2016 Schedules not included are omitted because of the absence of conditions under which they are required or because the required information is provided in the consolidated financial statements, including the notes thereto Pepco Holdings LLC and Subsidiary Companies Schedule II – Valuation and Qualifying Accounts Column A Column B Column C Column D Column E Additions and adjustments Description Balance at Charged to Charged Deductions Balance at (in millions) For the Year Ended December 31, 2018 (Successor) Allowance for uncollectible accounts $ 55 $ 28 $ 7 (a) $ 37 (b) $ 53 Deferred tax valuation allowance 13 — 2 7 8 Reserve for obsolete materials 2 — — — 2 For the Year Ended December 31, 2017 (Successor) Allowance for uncollectible accounts $ 80 $ 19 $ 6 (a) $ 50 (b) $ 55 Deferred tax valuation allowance 10 — 3 — 13 Reserve for obsolete materials 2 2 — 2 2 March 24, 2016 to December 31, 2016 (Successor) Allowance for uncollectible accounts $ 52 $ 65 $ 5 (a) $ 42 (b) $ 80 Deferred tax valuation allowance 63 — (53 ) — 10 Reserve for obsolete materials — 1 — (1 ) 2 January 1, 2016 to March 23, 2016 (Predecessor) Allowance for uncollectible accounts $ 56 $ 16 $ 2 (a) $ 22 (b) $ 52 Deferred tax valuation allowance 63 — — — 63 Reserve for obsolete materials — — — — — __________ (a) Primarily charges for late payments. (b) Write-off of individual accounts receivable. Potomac Electric Power Company (7) Pepco (i) Financial Statements (Item 8): Report of Independent Registered Public Accounting Firm dated February 8, 2019 of PricewaterhouseCoopers LLP Statements of Operations and Comprehensive Income for the Years Ended December 31, 2018, 2017 and 2016 Statements of Cash Flows for the Years Ended December 31, 2018, 2017 and 2016 Balance Sheets at December 31, 2018 and 2017 Statements of Changes in Shareholder's Equity for the Years Ended December 31, 2018, 2017 and 2016 Notes to Financial Statements (ii) Financial Statement Schedule: Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2018, 2017 and 2016 Schedules not included are omitted because of the absence of conditions under which they are required or because the required information is provided in the consolidated financial statements, including the notes thereto Potomac Electric Power Company Schedule II – Valuation and Qualifying Accounts Column A Column B Column C Column D Column E Additions and adjustments Description Balance at Charged to Charged Deductions Balance at (in millions) For the year ended December 31, 2018 Allowance for uncollectible accounts $ 21 $ 11 $ 3 (a) $ 14 (b) $ 21 Reserve for obsolete materials 1 — — — 1 For the year ended December 31, 2017 Allowance for uncollectible accounts $ 29 $ 8 $ 2 (a) $ 18 (b) $ 21 Reserve for obsolete materials 1 1 — 1 1 For the year ended December 31, 2016 Allowance for uncollectible accounts $ 17 $ 29 $ 3 (a) $ 20 (b) $ 29 Reserve for obsolete materials — 3 — 2 1 __________ (a) Primarily charges for late payments. (b) Write-off of individual accounts receivable. Delmarva Power & Light Company (8) DPL (i) Financial Statements (Item 8): Report of Independent Registered Public Accounting Firm dated February 8, 2019 of PricewaterhouseCoopers LLP Statements of Operations and Comprehensive Income (Loss) for the Years Ended December 31, 2018, 2017 and 2016 Statements of Cash Flows for the Years Ended December 31, 2018, 2017 and 2016 Balance Sheets at December 31, 2018 and 2017 Statements of Changes in Shareholder's Equity for the Years Ended December 31, 2018, 2017 and 2016 Notes to Financial Statements (ii) Financial Statement Schedule: Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2018, 2017 and 2016 Schedules not included are omitted because of the absence of conditions under which they are required or because the required information is provided in the consolidated financial statements, including the notes thereto Delmarva Power & Light Company Schedule II – Valuation and Qualifying Accounts Column A Column B Column C Column D Column E Additions and adjustments Description Balance at Charged to Charged Deductions Balance at (in millions) For the year ended December 31, 2018 Allowance for uncollectible accounts $ 16 $ 6 $ 2 (a) $ 11 (b) $ 13 Reserve for obsolete materials — — — — — For the year ended December 31, 2017 Allowance for uncollectible accounts $ 24 $ 3 $ 2 (a) $ 13 (b) $ 16 Reserve for obsolete materials — 1 — 1 — For the year ended December 31, 2016 Allowance for uncollectible accounts $ 17 $ 23 $ 2 (a) $ 18 (b) $ 24 Reserve for obsolete materials — 1 — 1 — __________ (a) Primarily charges for late payments. (b) Write-off of individual accounts receivable. Atlantic City Electric Company and Subsidiary Company (9) ACE (i) Financial Statements (Item 8): Report of Independent Registered Public Accounting Firm dated February 8, 2019 of PricewaterhouseCoopers LLP Consolidated Statements of Operations and Comprehensive Income (Loss) for the Years Ended December 31, 2018, 2017 and 2016 Consolidated Statements of Cash Flows for the Years Ended December 31, 2018, 2017 and 2016 Consolidated Balance Sheets at December 31, 2018 and 2017 Consolidated Statements of Changes in Shareholder's Equity for the Years Ended December 31, 2018, 2017 and 2016 Notes to Consolidated Financial Statements (ii) Financial Statement Schedule: Schedule II—Valuation and Qualifying Accounts for the Years Ended December 31, 2018, 2017 and 2016 Schedules not included are omitted because of the absence of conditions under which they are required or because the required information is provided in the consolidated financial statements, including the notes thereto Atlantic City Electric Company and Subsidiary Company Schedule II – Valuation and Qualifying Accounts Column A Column B Column C Column D Column E Additions and adjustments Description Balance at Charged to Charged Deductions Balance at (in millions) For the year ended December 31, 2018 Allowance for uncollectible accounts $ 18 $ 11 $ 2 (a) $ 12 (b) $ 19 Reserve for obsolete materials 1 — — — 1 For the year ended December 31, 2017 Allowance for uncollectible accounts $ 27 $ 8 $ 2 (a) $ 19 (b) $ 18 Reserve for obsolete materials 1 — — — 1 For the year ended December 31, 2016 Allowance for uncollectible accounts $ 17 $ 32 $ 2 (a) $ 24 (b) $ 27 Reserve for obsolete materials — 1 — — 1 __________ (a) Primarily charges for late payments. (b) Write-off of individual accounts receivable. |
Significant Accounting Polici_2
Significant Accounting Policies (Policies) | 12 Months Ended |
Dec. 31, 2018 | |
Accounting Policies [Abstract] | |
Description of Business (All Registrants) | Description of Business (All Registrants) Exelon is a utility services holding company engaged in the generation, delivery and marketing of energy through Generation and the energy distribution and transmission businesses through ComEd, PECO, BGE, Pepco, DPL and ACE. On March 23, 2016 , Exelon completed the merger with PHI, which became a wholly owned subsidiary of Exelon. PHI is a utility services holding company engaged through its principal wholly owned subsidiaries, Pepco, DPL and ACE, in the energy distribution and transmission businesses. See Note 5 — Mergers, Acquisitions and Dispositions for additional information regarding the merger transaction. Name of Registrant Business Service Territories Exelon Generation Generation, physical delivery and marketing of power across multiple geographical regions through its customer-facing business, Constellation, which sells electricity to both wholesale and retail customers. Generation also sells natural gas, renewable energy and other energy-related products and services. Six reportable segments: Mid-Atlantic, Midwest, New England, New York, ERCOT and Other Power Regions Commonwealth Edison Company Purchase and regulated retail sale of electricity Northern Illinois, including the City of Chicago Transmission and distribution of electricity to retail customers PECO Energy Company Purchase and regulated retail sale of electricity and natural gas Southeastern Pennsylvania, including the City of Philadelphia (electricity) Transmission and distribution of electricity and distribution of natural gas to retail customers Pennsylvania counties surrounding the City of Philadelphia (natural gas) Baltimore Gas and Electric Company Purchase and regulated retail sale of electricity and natural gas Central Maryland, including the City of Baltimore (electricity and natural gas) Transmission and distribution of electricity and distribution of natural gas to retail customers Pepco Holdings LLC Utility services holding company engaged, through its reportable segments Pepco, DPL and ACE Service Territories of Pepco, DPL and ACE Potomac Electric Purchase and regulated retail sale of electricity District of Columbia, and major portions of Montgomery and Prince George’s Counties, Maryland. Transmission and distribution of electricity to retail customers Delmarva Power & Light Company Purchase and regulated retail sale of electricity and natural gas Portions of Delaware and Maryland (electricity) Transmission and distribution of electricity and distribution of natural gas to retail customers Portions of New Castle County, Delaware (natural gas) Atlantic City Electric Company Purchase and regulated retail sale of electricity Portions of Southern New Jersey Transmission and distribution of electricity to retail customers Basis of Presentation (All Registrants) This is a combined annual report of all Registrants. The Notes to the Consolidated Financial Statements apply to the Registrants as indicated above in the Index to Combined Notes to Consolidated Financial Statements and parenthetically next to each corresponding disclosure. When appropriate, the Registrants are named specifically for their related activities and disclosures. Each of the Registrant’s Consolidated Financial Statements includes the accounts of its subsidiaries. All intercompany transactions have been eliminated. As a result of the merger with PHI, Exelon’s financial reporting reflects PHI’s consolidated financial results subsequent to the March 23, 2016 , acquisition date. Exelon has accounted for the merger transaction applying the acquisition method of accounting, which it has pushed-down to the consolidated financial statements of PHI such that the assets and liabilities of PHI are recorded at their respective fair values, and goodwill has been established as of the acquisition date. Accordingly, the consolidated financial statements of PHI for periods before and after the March 23, 2016 , acquisition date reflect different bases of accounting, and the results of operations and the financial positions of the predecessor and successor periods are not comparable. The acquisition method of accounting has not been pushed down to PHI’s wholly owned subsidiary utility registrants, Pepco, DPL and ACE. For financial statement purposes, beginning on March 24, 2016 , disclosures related to Exelon also apply to PHI, Pepco, DPL and ACE, unless otherwise noted. Through its business services subsidiary, BSC, Exelon provides its subsidiaries with a variety of support services at cost, including legal, human resources, financial, information technology and supply management services. PHI also has a business services subsidiary, PHISCO, which provides a variety of support services at cost, including legal, accounting, engineering, customer operations, distribution and transmission planning, asset management, system operations, and power procurement, to PHI operating companies. The costs of BSC and PHISCO are directly charged or allocated to the applicable subsidiaries. The results of Exelon’s corporate operations are presented as “Other” within the consolidated financial statements and include intercompany eliminations unless otherwise disclosed. Exelon owns 100% of Generation, PECO, BGE and PHI and more than 99% of ComEd. PHI owns 100% of Pepco, DPL and ACE. Generation owns 100% of its significant consolidated subsidiaries, either directly or indirectly, except for certain consolidated VIEs, including CENG and EGRP, of which Generation holds a 50.01% and 51% interest, respectively. The remaining interests in these consolidated VIEs are included in noncontrolling interests on Exelon’s and Generation’s Consolidated Balance Sheets. See Note 2 — Variable Interest Entities for additional information of Exelon’s and Generation’s consolidated VIEs. The Registrants consolidate the accounts of entities in which a Registrant has a controlling financial interest, after the elimination of intercompany transactions. Where the Registrants do not have a controlling financial interest in an entity, proportionate consolidation, equity method accounting or accounting for investments in equity securities without readily determinable fair value is applied. The Registrants apply proportionate consolidation when they have an undivided interest in an asset and are proportionately liable for their share of each liability associated with the asset. The Registrants proportionately consolidate their undivided ownership interests in jointly owned electric plants and transmission facilities. Under proportionate consolidation, the Registrants separately record their proportionate share of the assets, liabilities, revenues and expenses related to the undivided interest in the asset. The Registrants apply equity method accounting when they have significant influence over an investee through an ownership in common stock, which generally approximates a 20% to 50% voting interest. The Registrants apply equity method accounting to certain investments and joint ventures, including certain financing trusts of ComEd and PECO. Under equity method accounting, the Registrants report their interest in the entity as an investment and the Registrants’ percentage share of the earnings from the entity as single line items in their financial statements. The Registrants use accounting for investments in equity securities without readily determinable fair values if they lack significant influence, which generally results when they hold less than 20% of the common stock of an entity. Under accounting for investments in equity securities without readily determinable fair values, the Registrants report their investments at cost adjusted for changes from observable transactions for identical or similar investments of the same issuer, less impairment. Changes in measurement are reported in earnings. The accompanying consolidated financial statements have been prepared in accordance with GAAP for annual financial statements and in accordance with the instructions to Form 10-K and Regulation S-X promulgated by the SEC. |
Use Of Estimates (All Registrants) | Use of Estimates (All Registrants) The preparation of financial statements of each of the Registrants in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Areas in which significant estimates have been made include, but are not limited to, the accounting for nuclear decommissioning costs and other AROs, pension and other postretirement benefits, the application of purchase accounting, inventory reserves, allowance for uncollectible accounts, goodwill and asset impairments, derivative instruments, unamortized energy contracts, fixed asset depreciation, environmental costs and other loss contingencies, taxes and unbilled energy revenues. Actual results could differ from those estimates. |
Reclassifications (Exelon, ComEd, and BGE) | Prior Period Adjustments and Reclassifications (All Registrants) Certain prior year amounts in the Registrants' Consolidated Statements of Operations and Comprehensive Incom e, Consolidated Statements of Cash Flows, Consolidated Balance Sheets and Consolidated Statements of Changes in Shareholders' Equity have been recasted to reflect new accounting standards issued by the FASB and adopted as of January 1, 2018. See New Accounting Standards below for additional information. |
Accounting for the Effects of Regulation (Exelon, ComEd, PECO and BGE) | Accounting for the Effects of Regulation (Exelon and the Utility Registrants) For their regulated electric and gas operations, Exelon and the Utility Registrants reflect the effects of cost-based rate regulation in their financial statements, which is required for entities with regulated operations that meet the following criteria: 1) rates are established or approved by a third-party regulator; (2) rates are designed to recover the entities’ cost of providing services or products; and (3) there is a reasonable expectation that rates designed to recover costs can be charged to and collected from customers. Exelon and the Utility Registrants account for their regulated operations in accordance with regulatory and legislative guidance from the regulatory authorities having jurisdiction, principally the ICC, PAPUC, MDPSC, DCPSC, DPSC and NJBPU, under state public utility laws and the FERC under various Federal laws. Regulatory assets and liabilities are amortized and the related expense or revenue is recognized in the Consolidated Statements of Operations consistent with the recovery or refund included in customer rates. Exelon's regulatory assets and liabilities as of the balance sheet date are probable of being recovered or settled in future rates. If a separable portion of the Registrants' business was no longer able to meet the criteria discussed above, the affected entities would be required to eliminate from their consolidated financial statements the effects of regulation for that portion, which could have a material impact on their financial statements. See Note 4 — Regulatory Matters for additional information. With the exception of income tax-related regulatory assets and liabilities, Exelon and the Utility Registrants classify regulatory assets and liabilities with a recovery or settlement period greater than one year as both current and non-current in their Consolidated Balance Sheets, with the current portion representing the amount expected to be recovered from or settled to customers over the next twelve-month period as of the balance sheet date. Income tax-related regulatory assets and liabilities are classified entirely as non-current in Exelon's and the Utility Registrants’ Consolidated Balance Sheets to align with the classification of the related deferred income tax balances. Exelon and the Utility Registrants treat the impacts of a final rate order received after the balance sheet date but prior to the issuance of the financial statements as a non-recognized subsequent event, as the receipt of a final rate order is a separate and distinct event that has future impacts on the parties affected by the order. |
Revenues (All Registrants) | Revenues (All Registrants) Operating Revenues. The Registrants’ operating revenues generally consist of revenues from contracts with customers involving the sale and delivery of energy commodities and related products and services, utility revenues from alternative revenue programs (ARP), and realized and unrealized revenues recognized under mark-to-market energy commodity derivative contracts. The Registrants recognize revenue from contracts with customers to depict the transfer of goods or services to customers in an amount that the entities expect to be entitled to in exchange for those goods or services. Generation’s primary sources of revenue include competitive sales of power, natural gas, and other energy-related products and services. The Utility Registrants’ primary sources of revenue include regulated electric and natural gas tariff sales, distribution and transmission services. At the end of each month, the Registrants accrue an estimate for the unbilled amount of energy delivered or services provided to customers. ComEd records ARP revenue for its best estimate of the electric distribution, energy efficiency, and transmission revenue impacts resulting from future changes in rates that ComEd believes are probable of approval by the ICC and FERC in accordance with its formula rate mechanisms. BGE, Pepco and DPL record ARP revenue for their best estimate of the electric and natural gas distribution revenue impacts resulting from future changes in rates that they believe are probable of approval by the MDPSC and/or DCPSC in accordance with their revenue decoupling mechanisms. PECO, BGE, Pepco, DPL and ACE record ARP revenue for their best estimate of the transmission revenue impacts resulting from future changes in rates that they believe are probable of approval by FERC in accordance with their formula rate mechanisms. See Note 4 — Regulatory Matters and Note 23 — Supplemental Financial Information for additional information. Option Contracts, Swaps and Commodity Derivatives. Certain option contracts and swap arrangements that meet the definition of derivative instruments are recorded at fair value with subsequent changes in fair value recognized as revenue or expense. The classification of revenue or expense is based on the intent of the transaction. To the extent a Utility Registrant receives full cost recovery for energy procurement and related costs from retail customers, it records the fair value of its energy swap contracts with unaffiliated suppliers as well as an offsetting regulatory asset or liability in its Consolidated Balance Sheets. See Note 4 — Regulatory Matters and Note 12 — Derivative Financial Instruments for additional information. |
Revenue, Transaction Price Measurement, Tax Exclusion [Policy Text Block] | Taxes Directly Imposed on Revenue-Producing Transactions. The Registrants collect certain taxes from customers such as sales and gross receipts taxes, along with other taxes, surcharges and fees, that are levied by state or local governments on the sale or distribution of gas and electricity. Some of these taxes are imposed on the customer, but paid by the Registrants, while others are imposed on the Registrants. Where these taxes are imposed on the customer, such as sales taxes, they are reported on a net basis with no impact to the Consolidated Statements of Operations and Comprehensive Income. However, where these taxes are imposed on the Registrants, such as gross receipts taxes or other surcharges or fees, they are reported on a gross basis. Accordingly, revenues are recognized for the taxes collected from customers along with an offsetting expense. Se e Note 23 — Supplemental Financial Information for Generation’s, ComEd’s, PECO’s, BGE’s, Pepco's, DPL's and ACE's utility taxes that are presented on a gross basis. |
Income Taxes (All Registrants) | Income Taxes (All Registrants) Deferred Federal and state income taxes are recorded on significant temporary differences between the book and tax basis of assets and liabilities and for tax benefits carried forward. Investment tax credits have been deferred in the Registrants’ Consolidated Balance Sheets and are recognized in book income over the life of the related property. The Registrants account for uncertain income tax positions using a benefit recognition model with a two-step approach; a more-likely-than-not recognition criterion; and a measurement approach that measures the position as the largest amount of tax benefit that is greater than 50% likely of being realized upon ultimate settlement. If it is not more-likely-than-not that the benefit of the tax position will be sustained on its technical merits, no benefit is recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold. The Registrants recognize accrued interest related to unrecognized tax benefits in Interest expense or Other income and deductions (interest income) and recognize penalties related to unrecognized tax benefits in Other, net in their Consolidated Statements of Operations and Comprehensive Income. Pursuant to the IRC and relevant state taxing authorities, Exelon and its subsidiaries file consolidated or combined income tax returns for Federal and certain state jurisdictions where allowed or required. See Note 14 — Income Taxes for additional information. |
Cash and Cash Equivalents (All Registrants) | Cash and Cash Equivalents (All Registrants) The Registrants consider investments purchased with an original maturity of three months or less to be cash equivalents. Restricted Cash and Cash Equivalents (All Registrants) Restricted cash and cash equivalents represent funds that are restricted to satisfy designated current liabilities. As of December 31, 2018 and 2017 , the Registrants' restricted cash and cash equivalents primarily represented the following items: Registrant Description Exelon Payment of medical, dental, vision and long-term disability benefits, in addition to the items listed for Generation and the Utility Registrants. Generation Project-specific nonrecourse financing structures for debt service and financing of operations of the underlying entities. ComEd Collateral held from suppliers associated with energy and REC procurement contracts, any over-recovered RPS costs and alternative compliance payments received from RES pursuant to FEJA and costs for the remediation of an MGP site. PECO Proceeds from the sales of assets that were subject to PECO’s mortgage indenture. BGE Proceeds from the loan program for the completion of certain energy efficiency measures and collateral held from energy suppliers. PHI Payment of merger commitments, collateral held from its energy suppliers associated with procurement contracts and repayment of transition bonds. Pepco Payment of merger commitments and collateral held from energy suppliers. DPL Collateral held from energy suppliers. ACE Repayment of transition bonds and collateral held from energy suppliers. Restricted cash and cash equivalents not available to satisfy current liabilities are classified as noncurrent assets. As of December 31, 2018 and 2017 , the Registrants' noncurrent restricted cash and cash equivalents primarily represented ComEd’s over-recovered RPS costs and alternative compliance payments received from RES pursuant to FEJA and costs for the remediation of an MGP site, and ACE’s repayment of transition bonds. |
Allowance for Uncollectible Accounts (All Registrants) | Allowance for Uncollectible Accounts (All Registrants) The allowance for uncollectible accounts reflects the Registrants’ best estimates of losses on the customers' accounts receivable balances. For Generation, the allowance is based on accounts receivable aging historical experience and other currently available information. Utility Registrants estimate the allowance by applying loss rates developed specifically for each company to the outstanding receivable balance by customer risk segment. Utility Registrants' customer accounts are written off consistent with approved regulatory requirements. |
Variable Interest Entities (All Registrants) | Variable Interest Entities (All Registrants) Exelon accounts for its investments in and arrangements with VIEs based on the following specific requirements: • requires an entity to qualitatively assess whether it should consolidate a VIE based on whether the entity has a controlling financial interest, • requires an ongoing reconsideration of this assessment instead of only upon certain triggering events, and • requires the entity that consolidates a VIE (the primary beneficiary) to disclose (1) the assets of the consolidated VIE, if they can be used to only settle specific obligations of the consolidated VIE, and (2) the liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary. |
Inventories (All Registrants) | Inventories (All Registrants) Inventory is recorded at the lower of weighted average cost or net realizable value. Provisions are recorded for excess and obsolete inventory. Fossil fuel, materials and supplies, and emissions allowances are generally included in inventory when purchased. Fossil fuel and emissions allowances are expensed to purchased power and fuel expense when used or sold. Materials and supplies generally includes transmission, distribution and generating plant materials and are expensed to operating and maintenance or capitalized to property, plant and equipment, as appropriate, when installed or used. |
Marketable Securities (All Registrants) | Debt and Equity Security Investments (Exelon and Generation ) Debt Security Investments. Debt securities are reported at fair value and classified as available-for-sale securities. Unrealized gains and losses, net of tax, are reported in OCI. Equity Security Investments without Readily Determinable Fair Values. Exelon has certain equity securities without readily determinable fair values. Exelon has elected to use the practicability exception to measure these investments, defined as cost adjusted for changes from observable transactions for identical or similar investments of the same issuer, less impairment. Changes in measurement are reported in earnings. Equity Security Investments with Readily Determinable Fair Values. Equity securities held in the NDT funds are classified as equity securities with readily determinable fair values. Realized and unrealized gains and losses, net of tax, on Generation’s NDT funds associated with the Regulatory Agreement Units are included in regulatory liabilities at Exelon, ComEd and PECO and in Noncurrent payables to affiliates at Generation and in Noncurrent receivables from affiliates at ComEd and PECO. Realized and unrealized gains and losses, net of tax, on Generation’s NDT funds associated with the Non-Regulatory Agreement Units are included in earnings at Exelon and Generation. Exelon's and Generation's NDT funds are classified as current or noncurrent assets, depending on the timing of the decommissioning activities and income taxes on trust earnings. |
Property Plant And Equipment (All Registrants) | Property, Plant and Equipment (All Registrants) Property, plant and equipment is recorded at original cost. Original cost includes construction-related direct labor and material costs. The Utility Registrants also include indirect construction costs including labor and related costs of departments associated with supporting construction activities. When appropriate, original cost also includes capitalized interest for Generation, Exelon Corporate and PHI and AFUDC for regulated property at the Utility Registrants. The cost of repairs and maintenance, including planned major maintenance activities and minor replacements of property, is charged to Operating and maintenance expense as incurred. Third parties reimburse the Utility Registrants for all or a portion of expenditures for certain capital projects. Such contributions in aid of construction costs (CIAC) are recorded as a reduction to Property, plant and equipment, net. DOE SGIG and other funds reimbursed to the Utility Registrants have been accounted for as CIAC. For Generation, upon retirement, the cost of property is generally charged to accumulated depreciation in accordance with the composite and group methods of depreciation. Upon replacement of an asset, the costs to remove the asset, net of salvage, are capitalized to gross plant when incurred as part of the cost of the newly-installed asset and recorded to depreciation expense over the life of the new asset. Removal costs, net of salvage, incurred for property that will not be replaced is charged to Operating and maintenance expense as incurred. For the Utility Registrants, upon retirement, the cost of property, net of salvage, is charged to accumulated depreciation consistent with the composite and group methods of depreciation. Depreciation expense at ComEd, BGE, Pepco, DPL and ACE includes the estimated cost of dismantling and removing plant from service upon retirement. Actual incurred removal costs are applied against a related regulatory liability or recorded to a regulatory asset if in excess of previously collected removal costs. PECO’s removal costs are capitalized to accumulated depreciation when incurred, and recorded to depreciation expense over the life of the new asset constructed consistent with PECO’s regulatory recovery method. Capitalized Software. Certain costs, such as design, coding, and testing incurred during the application development stage of software projects that are internally developed or purchased for operational use are capitalized within Property, plant and equipment. Such capitalized amounts are amortized ratably over the expected lives of the projects when they become operational, generally not to exceed five years. Certain other capitalized software costs are being amortized over longer lives based on the expected life or pursuant to prescribed regulatory requirements. Capitalized Interest and AFUDC. During construction, Exelon and Generation capitalize the costs of debt funds used to finance non-regulated construction projects. Capitalization of debt funds is recorded as a charge to construction work in progress and as a non-cash credit to interest expense. AFUDC is the cost, during the period of construction, of debt and equity funds used to finance construction projects for regulated operations. AFUDC is recorded to construction work in progress and as a non-cash credit to an allowance that is included in interest expense for debt-related funds and other income and deductions for equity-related funds. The rates used for capitalizing AFUDC are computed under a method prescribed by regulatory authorities. |
Nuclear Fuel (Exelon and Generation) | Nuclear Fuel (Exelon and Generation) The cost of nuclear fuel is capitalized within Property, plant and equipment and charged to fuel expense using the unit-of-production method. Any potential future SNF disposal fees will be expensed through fuel expense. Additionally, certain on-site SNF storage costs are being reimbursed by the DOE since a DOE (or government-owned) long-term storage facility has not been completed. |
Nuclear Outage Costs (Exelon and Generation) | Nuclear Outage Costs (Exelon and Generation) Costs associated with nuclear outages, including planned major maintenance activities, are expensed to Operating and maintenance expense or capitalized to Property, plant and equipment (based on the nature of the activities) in the period incurred. |
Depreciation, Depletion, and Amortization (All Registrants) | Depreciation and Amortization (All Registrants) Except for the amortization of nuclear fuel, depreciation is generally recorded over the estimated service lives of property, plant and equipment on a straight-line basis using the group, composite or unitary methods of depreciation. The group approach is typically for groups of similar assets that have approximately the same useful lives and the composite approach is used for dissimilar assets that have different lives. Under both methods, a reporting entity depreciates the assets over the average life of the assets in the group. The Utility Registrants' depreciation expense includes the estimated cost of dismantling and removing plant from service upon retirement, which is consistent with each utility's regulatory recovery method. The estimated service lives for the Registrants are based on a combination of depreciation studies, historical retirements, site licenses and management estimates of operating costs and expected future energy market conditions. See Note 8 — Early Plant Retirements for additional information on the impacts of expected and potential early plant retirements. See Note 6 — Property, Plant and Equipment for additional information regarding depreciation. Amortization of regulatory assets and liabilities are recorded over the recovery or refund period specified in the related legislation or regulatory order or agreement. When the recovery or refund period is less than one year, amortization is recorded to the line item in which the deferred cost or income would have originally been recorded in the Utility Registrants’ Consolidated Statements of Operations and Comprehensive Income. Amortization of ComEd’s electric distribution and energy efficiency formula rate regulatory assets and the Utility Registrants' transmission formula rate regulatory assets is recorded to Operating revenues. Amortization of income tax related regulatory assets and liabilities is generally recorded to Income tax expense. With the exception of the regulatory assets and liabilities discussed above, when the recovery period is more than one year, the amortization is generally recorded to Depreciation and amortization in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. |
Asset Retirement Obligations (All Registrants) | Asset Retirement Obligations (All Registrants) Generation estimates and recognizes a liability for its legal obligation to perform asset retirement activities even though the timing and/or methods of settlement may be conditional on future events. Generation generally updates its nuclear decommissioning ARO annually, unless circumstances warrant more frequent updates, based on its annual evaluation of cost escalation factors and probabilities assigned to the multiple outcome scenarios within its probability-weighted discounted cash flow models. Generation’s multiple outcome scenarios are generally based on decommissioning cost studies which are updated, on a rotational basis, for each of Generation’s nuclear units at least every five years, unless circumstances warrant more frequent updates. AROs are accreted throughout each year to reflect the time value of money for these present value obligations through a charge to Operating and maintenance expense in the Consolidated Statements of Operations and Comprehensive Income or, in the case of the Utility Registrants' accretion, through an increase to regulatory assets. |
Guarantees (All Registrants) | Guarantees (All Registrants) The Registrants recognize, at the inception of a guarantee, a liability for the fair market value of the obligations they have undertaken by issuing the guarantee, including the ongoing obligation to perform over the term of the guarantee in the event that the specified triggering events or conditions occur. The liability that is initially recognized at the inception of the guarantee is reduced as the Registrants are released from risk under the guarantee. Depending on the nature of the guarantee, the release from risk of the Registrant may be recognized only upon the expiration or settlement of the guarantee or by a systematic and rational amortization method over the term of the guarantee. |
Long-lived Assets (All Registrants) | Long-Lived Assets (All Registrants). The Registrants evaluate the carrying value of their long-lived assets or asset groups, excluding goodwill, when circumstances indicate the carrying value of those assets may not be recoverable. Indicators of impairment may include a deteriorating business climate, including, but not limited to, declines in energy prices, condition of the asset, specific regulatory disallowance, or plans to dispose of a long-lived asset significantly before the end of its useful life. The Registrants determine if long-lived assets and asset groups are impaired by comparing the undiscounted expected future cash flows to the carrying value. When the undiscounted cash flow analysis indicates a long-lived asset or asset group is not recoverable, the amount of the impairment loss is determined by measuring the excess of the carrying amount of the long-lived asset or asset group over its fair value. |
Goodwill (All Registrants) | Goodwill (Exelon, ComEd and PHI). Goodwill represents the excess of the purchase price paid over the estimated fair value of the net assets acquired and liabilities assumed in the acquisition of a business. Goodwill is not amortized, but is tested for impairment at least annually or on an interim basis if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. |
Equity Method Investments (All Registrants) | Equity Method Investments (Exelon and Generation). Exelon and Generation regularly monitor and evaluate equity method investments to determine whether they are impaired. An impairment is recorded when the investment has experienced a decline in value that is other-than-temporary in nature. Additionally, if the entity in which Generation holds an investment recognizes an impairment loss, Exelon and Generation would record their proportionate share of that impairment loss and evaluate the investment for an other-than-temporary decline in value. |
Derivatives Financial Instruments (All Registrants) | Derivative Financial Instruments (All Registrants) All derivatives are recognized on the balance sheet at their fair value unless they qualify for certain exceptions, including the normal purchases and normal sales exception. For derivatives intended to serve as economic hedges, changes in fair value are recognized in earnings each period. Amounts classified in earnings are included in Operating revenue, Purchased power and fuel, Interest expense or Other, net in the Consolidated Statements of Operations and Comprehensive Income based on the activity the transaction is economically hedging. While the majority of the derivatives serve as economic hedges, there are also derivatives entered into for proprietary trading purposes, subject to Exelon’s Risk Management Policy, and changes in the fair value of those derivatives are recorded in revenue in the Consolidated Statements of Operations and Comprehensive Income. At the Utility Registrants, changes in fair value may be recorded as a regulatory asset or liability if there is an ability to recover or return the associated costs. Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing cash flows in the Consolidated Statements of Cash Flows, depending on the nature of each transaction. On July 1, 2018, Exelon and Generation de-designated its fair value and cash flow hedges. See Note 4 — Regulatory Matters and Note 12 — Derivative Financial Instruments for additional information. As part of Generation’s energy marketing business, Generation enters into contracts to buy and sell energy to meet the requirements of its customers. These contracts include short-term and long-term commitments to purchase and sell energy and energy-related products in the energy markets with the intent and ability to deliver or take delivery of the underlying physical commodity. Normal purchases and normal sales are contracts where physical delivery is probable, quantities are expected to be used or sold in the normal course of business over a reasonable period of time and will not be financially settled. Revenues and expenses on derivative contracts that qualify, and are designated, as normal purchases and normal sales are recognized when the underlying physical transaction is completed. While these contracts are considered derivative financial instruments, they are not required to be recorded at fair value, but rather are recorded on an accrual basis of accounting. |
Retirement Benefits (All Registrants) | Retirement Benefits (All Registrants) Exelon sponsors defined benefit pension plans and other postretirement benefit plans for essentially all employees. The measurement of the plan obligations and costs of providing benefits under these plans involve various factors assumptions, and accounting elections. The impact of assumption changes or experience different from that assumed on pension and other postretirement benefit obligations is recognized over time rather than immediately recognized in the Consolidated Statements of Operations and Comprehensive Income. Gains or losses in excess of the greater of ten percent of the projected benefit obligation or the MRV of plan assets are amortized over the expected average remaining service period of plan participants. |
Investment, Policy [Policy Text Block] | Debt Security Investments (Exelon and Generation). Declines in the fair value of debt security investments below the cost basis are reviewed to determine if such decline is other-than-temporary. If the decline is determined to be other-than-temporary, the amount of the impairment loss is included in earnings. Equity Security Investments (Exelon and Generation). Equity investments with readily determinable fair values are measured and recorded at fair value with any changes in fair value recorded through earnings. Investments in equity securities without readily determinable fair values are qualitatively assessed for impairment each reporting period. If it is determined that the equity security is impaired on the basis of the qualitative assessment, an impairment loss will be recognized in earnings to the amount by which the security’s carrying amount exceeds its fair value. |
New Accounting Pronouncements and Changes in Accounting Principles [Text Block] | Prior Period Adjustments and Reclassifications (All Registrants) Certain prior year amounts in the Registrants' Consolidated Statements of Operations and Comprehensive Incom e, Consolidated Statements of Cash Flows, Consolidated Balance Sheets and Consolidated Statements of Changes in Shareholders' Equity have been recasted to reflect new accounting standards issued by the FASB and adopted as of January 1, 2018. See New Accounting Standards below for additional information. |
New Accounting Pronouncements, Policy [Policy Text Block] | New Accounting Standards Adopted in 2018: In 2018, the Registrants adopted the following new authoritative accounting guidance issued by the FASB. Defined Benefit Plan Disclosures (Issued August 2018). Eliminates existing disclosure requirements related to amounts in Accumulated other comprehensive income expected to be recognized in Net periodic benefit cost over the next year and the effects of a one-percentage-point change in the assumed health care cost trend rates. In addition, new disclosures were added such as the weighted-average interest crediting rates for cash balance plans and an explanation for the reasons for significant gains and losses related to changes in the benefit obligation. The standard is effective January 1, 2021, with early adoption permitted, and must be applied retrospectively. Exelon early adopted this standard in the fourth quarter of 2018. See Note 16 — Retirement Benefits for additional information. Fair Value Measurement Disclosures (Issued August 2018). Updates the disclosure requirements for fair value measurements to improve the usefulness of information for financial statement users. The guidance removes the requirements to disclose (1) the amount of and reasons for transfers between Level 1 and Level 2, (2) the policy for timing of transfers between levels, and (3) the valuation processes for Level 3 fair value measurements and adds a requirement to disclose the range and weighted average of significant unobservable inputs used to develop Level 3 fair value measurements. The standard is effective January 1, 2020, with early adoption permitted. The amendments to remove disclosures must be applied retrospectively and can be early adopted, while the amendments to add disclosures must be applied prospectively and adoption can be delayed until the effective date. The Registrants early adopted, in the fourth quarter of 2018, the amendments to remove disclosures and will adopt the amendments to add disclosures in the first quarter of 2020. The impact of the new disclosures is not expected to be material to the Registrants’ consolidated financial statements. See Note 11 — Fair Value of Financial Assets and Liabilities for additional information. Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income (Issued February 2018). Provides an election for a reclassification from AOCI to Retained earnings to eliminate the stranded tax effects resulting from the TCJA. This standard is effective January 1, 2019, with early adoption permitted, and may be applied either in the period of adoption or retrospective to each period in which the effects of the TCJA were recognized. Exelon early adopted this standard and elected to apply the guidance retrospectively as of December 31, 2017, which resulted in an increase to Exelon’s Retained earnings and Accumulated other comprehensive loss of $539 million in its Consolidated Balance Sheet and Consolidated Statement of Changes in Shareholders' Equity related to deferred income taxes associated with Exelon’s pension and OPEB obligations. There was no impact for Generation or the Utility Registrants. Exelon's accounting policy is to release the stranded tax effects from AOCI related to its pension and OPEB plans under a portfolio (or aggregate) approach as an entire pension or OPEB plan is liquidated or terminated. See Note 21 — Changes in Accumulated Other Comprehensive Income for additional information. Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost (Issued March 2017). Changes the accounting and presentation of pension and OPEB costs at the plan sponsor (i.e., Exelon) level. The guidance requires plan sponsors to report the service cost and other non-service cost components of net periodic pension cost and net periodic OPEB cost (together, net benefit cost) separately. Under the new guidance, service cost is presented as part of income from operations and the other non-service cost components are classified outside of income from operations in the Consolidated Statements of Operations and Comprehensive Income. Additionally, service cost is the only component eligible for capitalization on a prospective basis beginning on January 1, 2018. Under prior GAAP, the total amount of net benefit cost was recorded as part of income from operations and all components were eligible for capitalization. Exelon applied the presentation of the service component and the other non-service cost components of net benefit costs retrospectively and, accordingly, have recasted those amounts, which were not material, in its Consolidated Statement of Operations and Comprehensive Income in prior periods presented. Exelon elected the practical expedient that permits an employer to use the amounts disclosed in its pension and other postretirement benefit plan note for the comparative periods as the estimation basis for applying the retrospective presentation requirements. In Exelon’s consolidated financial statements, non-service cost components of pension and OPEB cost capitalizable under a regulatory framework were prospectively reported as regulatory assets (previously, they were capitalizable under pension and OPEB accounting guidance and reported as PP&E). These regulatory assets are amortized outside of operating income. See Note 16 — Retirement Benefits for additional information. Generation, ComEd, PECO, BGE, BSC, PHI, Pepco, DPL, ACE and PHISCO participate in Exelon’s single employer pension and OPEB plans and apply multi-employer accounting. Multi-employer accounting was not impacted by this standard; therefore, Exelon's subsidiary financial statements did not change upon its adoption. Statement of Cash Flows: Classification of Restricted Cash (Issued November 2016). The standard states that amounts generally described as restricted cash and restricted cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows (instead of being presented as cash flow activities). The Registrants applied the new guidance using the full retrospective method and, accordingly, have recasted the presentation of restricted cash in their Consolidated Statements of Cash Flows in the prior periods presented. See Note 23 — Supplemental Financial Information for additional information. Recognition and Measurement of Financial Assets and Financial Liabilities (Issued January 2016). Eliminates the available-for-sale and cost method classification for equity securities and requires that all equity investments (other than those accounted for using the equity method of accounting) be measured and recorded at fair value with any changes in fair value recorded through earnings and, for equity investments without a readily determinable fair value, provides a measurement alternative of cost less impairment plus or minus adjustments for observable price changes in identical or similar assets. In addition, equity investments without readily determinable fair values must be qualitatively assessed for impairment each reporting period and fair value determined if any significant impairment indicators exist. If fair value is less than carrying value, the impairment is recorded through net income immediately in the period in which it is identified. The guidance does not impact the classification or measurement of investments in debt securities. The guidance also amends several disclosure requirements, including requiring i) financial assets and financial liabilities to be presented separately in the balance sheet or note, grouped by measurement category and form, ii) disclosure of the methods and significant assumptions used to estimate fair value or a description of the changes in the methods and assumptions used to estimate fair value, and iii) for financial assets and liabilities measured at amortized cost, disclosure of the fair value of the amount that would be received to sell the asset or paid to transfer the liability. The guidance was applied using a modified retrospective transition approach with a cumulative effect adjustment to retained earnings for initial application of the guidance at the date of adoption. The Registrants recorded an insignificant adjustment to opening retained earnings as of January 1, 2018 related to unrealized gains/losses on available for sale equity securities. See Note 21 — Changes in Accumulated Other Comprehensive Income for additional information. Revenue from Contracts with Customers (Issued May 2014 and subsequently amended to address implementation questions). Changes the criteria for recognizing revenue from a contract with a customer. The new standard replaces existing guidance on revenue recognition, including most industry specific guidance, with a five-step model for recognizing and measuring revenue from contracts with customers. The objective of the new standard is to provide a single, comprehensive revenue recognition model for all contracts with customers to improve comparability within industries, across industries, and across capital markets. The underlying principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. The guidance also requires a number of disclosures regarding the nature, amount, timing, and uncertainty of revenue and the related cash flows. The guidance can be applied retrospectively to each prior reporting period presented (full retrospective method) or retrospectively with a cumulative effect adjustment to retained earnings for initial application of the guidance at the date of initial adoption (modified retrospective method). The Registrants applied the new guidance using the full retrospective method and, accordingly, have recasted certain amounts in their Consolidated Statements of Operations and Comprehensive Income, Consolidated Statements of Cash Flows, Consolidated Balance Sheets, Consolidated Statements of Changes in Shareholders' Equity and Combined Notes to Consolidated Financial Statements in the prior periods presented. The amounts recasted in the Registrants' 2017 and 2016 Consolidated Statements of Operations and Comprehensive Income are shown in the table below. The amounts recasted in the Registrants’ Consolidated Statements of Cash Flows, Consolidated Balance Sheets, Consolidated Statements of Changes in Shareholders' Equity and Combined Notes to Consolidated Financi al Statements were not material. See Note 3 — Revenue from Contracts with Customers for additional information. Successor For the year ended December 31, 2017 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Operating Revenues - As reported Competitive business revenues $ 17,360 $ — $ — $ — $ — $ — $ — $ — $ — Rate-regulated utility revenues 16,171 — — — — — — — — Operating revenues — 17,351 — — — — — — — Electric operating revenues — — 5,521 2,369 2,484 4,468 2,152 1,131 1,184 Natural gas operating revenues — — — 494 676 161 — 161 — Operating revenues from affiliates — 1,115 15 7 16 50 6 8 2 Total operating revenues $ 33,531 $ 18,466 $ 5,536 $ 2,870 $ 3,176 $ 4,679 $ 2,158 $ 1,300 $ 1,186 Operating Revenues - Adjustments Competitive business revenues $ 34 $ — $ — $ — $ — $ — $ — $ — $ — Rate-regulated utility revenues (207 ) — — — — — — — — Operating revenues — 34 — — — — — — — Electric operating revenues — — (43 ) — (100 ) (40 ) (26 ) (6 ) (8 ) Natural gas operating revenues — — — — (24 ) — — — — Revenues from alternative revenue programs 207 — 43 — 124 40 26 6 8 Operating revenues from affiliates — — — — — — — — Total operating revenues $ 34 $ 34 $ — $ — $ — $ — $ — $ — $ — Operating Revenues - Retrospective application Competitive business revenues $ 17,394 $ — $ — $ — $ — $ — $ — $ — $ — Rate-regulated utility revenues 15,964 — — — — — — — — Operating revenues — 17,385 — — — — — — — Electric operating revenues — — 5,478 2,369 2,384 4,428 2,126 1,125 1,176 Natural gas operating revenues — — — 494 652 161 — 161 — Revenues from alternative revenue programs 207 — 43 — 124 40 26 6 8 Operating revenues from affiliates — 1,115 15 7 16 50 6 8 2 Total operating revenues $ 33,565 $ 18,500 $ 5,536 $ 2,870 $ 3,176 $ 4,679 $ 2,158 $ 1,300 $ 1,186 Successor Predecessor March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 For the year ended December 31, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Operating Revenues - As reported Competitive business revenues $ 16,324 $ — $ — $ — $ — $ — $ — $ — $ — $ — Rate-regulated utility revenues 15,036 — — — — — — — — — Operating revenues — 16,312 — — — — — — — — Electric operating revenues — — 5,239 2,524 2,603 2,181 1,122 1,254 3,506 1,096 Natural gas operating revenues — — — 462 609 — 148 — 92 57 Operating revenues from affiliates — 1,439 15 8 21 5 7 3 45 — Total operating revenues $ 31,360 $ 17,751 $ 5,254 $ 2,994 $ 3,233 $ 2,186 $ 1,277 $ 1,257 $ 3,643 $ 1,153 Operating Revenues - Adjustments Competitive business revenues $ 6 $ — $ — $ — $ — $ — $ — $ — $ — $ — Rate-regulated utility revenues (48 ) — — — — — — — — — Operating revenues — 6 — — — — — — — — Electric operating revenues — — 24 — (72 ) (14 ) 6 (9 ) (43 ) 26 Natural gas operating revenues — — — — 19 — — — — — Revenues from alternative revenue programs 48 — (24 ) — 53 14 (6 ) 9 43 (26 ) Operating revenues from affiliates — — — — — — — — — — Total operating revenues $ 6 $ 6 $ — $ — $ — $ — $ — $ — $ — $ — Operating Revenues - Retrospective application Competitive business revenues $ 16,330 $ — $ — $ — $ — $ — $ — $ — $ — $ — Rate-regulated utility revenues 14,988 — — — — — — — — — Operating revenues — 16,318 — — — — — — — — Electric operating revenues — — 5,263 2,524 2,531 2,167 1,128 1,245 3,463 1,122 Natural gas operating revenues — — — 462 628 — 148 — 92 57 Revenues from alternative revenue programs 48 — (24 ) — 53 14 (6 ) 9 43 (26 ) Operating revenues from affiliates — 1,439 15 8 21 5 7 3 45 — Total operating revenues $ 31,366 $ 17,757 $ 5,254 $ 2,994 $ 3,233 $ 2,186 $ 1,277 $ 1,257 $ 3,643 $ 1,153 New Accounting Standards Adopted as of January 1, 2019: The following new authoritative accounting guidance issued by the FASB was adopted as of January 1, 2019 and will be reflected by the Registrants in their consolidated financial statements beginning in the first quarter of 2019. Cloud Computing Arrangements (Issued August 2018). Aligns the requirements for capitalizing costs incurred to implement a cloud computing arrangement with the internal-use software guidance. As a result, certain implementation costs incurred in a cloud computing arrangement that are currently expensed as incurred will be deferred and amortized over the non-cancellable term of the arrangement plus any reasonably certain renewal periods. The standard is effective January 1, 2020, with early adoption permitted, and can be applied using either a prospective or retrospective transition approach. A retrospective approach requires a cumulative-effect adjustment to retained earnings as of the beginning of the period of adoption. The Registrants early adopted this standard using a prospective approach as of January 1, 2019. The new guidance is not expected to have a material impact on the Registrants’ financial statements. Leases (Issued February 2016). Increases transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The Registrants adopted the standard on January 1, 2019. The new standard requires lessees to recognize both the right-of-use assets and lease liabilities in the balance sheet for most leases, whereas under previous GAAP only finance lease liabilities (referred to as capital leases) were recognized in the balance sheet. In addition, the definition of a lease has been revised which may result in changes to the classification of an arrangement as a lease. Under the new standard, an arrangement that conveys the right to control the use of an identified asset by obtaining substantially all of its economic benefits and directing how it is used is a lease, whereas the previous definition focuses on the ability to control the use of the asset or to obtain its output. Quantitative and qualitative disclosures related to the amount, timing and judgments of an entity’s accounting for leases and the related cash flows are expanded. Disclosure requirements apply to both lessees and lessors, whereas previous disclosures related only to lessees. The recognition, measurement, and presentation of expenses and cash flows arising from a lease by a lessee have not significantly changed from previous GAAP. Lessor accounting is also largely unchanged. The new standard provides a number of transition practical expedients, which the Registrants have elected, including: • a "package of three" expedients that must be taken together and allow entities to (1) not reassess whether existing contracts contain leases, (2) carryforward the existing lease classification, and (3) not reassess initial direct costs associated with existing leases, • an implementation expedient which allows the requirements of the standard in the period of adoption with no restatement of prior periods, and • a land easement expedient which allows entities to not evaluate land easements under the new standard at adoption if they were not previously accounted for as leases. The Registrants have assessed the lease standard and executed a detailed implementation plan in preparation for adoption, which included the following key activities: • Developed a complete lease inventory and abstracted the required data attributes into a lease accounting system that supports the Registrants' lease portfolios and integrates with existing systems. • Evaluated the transition practical expedients available under the standard. • Identified, assessed and documented technical accounting issues, policy considerations and financial reporting implications. • Identified and implemented changes to processes and controls to ensure all impacts of the new standard are effectively addressed. The adoption of the new standard is expected to result in right of use assets and lease obligations for operating leases recorded in the Registrants’ Consolidated Balance Sheets on January 1, 2019 of approximately: Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE ROU Assets $1,400-$1,500 $1,000-$1,100 $5-$10 $1-$5 $100-$120 $250-$270 $60-$65 $70-$75 $20-$25 Lease Liabilities $1,600-$1,700 $1,200-$1,300 $5-$10 $1-$5 $100-$120 $300-$320 $60-$65 $75-$80 $20-$25 The impact of adopting the new standard on retained earnings as of January 1, 2019 is expected to be immaterial. New Accounting Standards Issued and Not Yet Adopted as of December 31, 2018: The following new authoritative accounting guidance issued by the FASB has not yet been adopted and reflected by the Registrants in their consolidated financial statements as of December 31, 2018. Unless otherwise indicated, the Registrants are currently assessing the impacts such guidance may have (which could be material) in their Consolidated Balance Sheets, Consolidated Statements of Operations and Comprehensive Income, Consolidated Statements of Cash Flows and disclosures, as well as the potential to early adopt where applicable. The Registrants have assessed other FASB issuances of new standards which are not listed below given the current expectation that such standards will not significantly impact the Registrants' financial reporting. Goodwill Impairment (Issued January 2017). Simplifies the accounting for goodwill impairment by removing Step 2 of the current test, which requires calculation of a hypothetical purchase price allocation. Under the revised guidance, goodwill impairment will be measured as the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill (currently Step 1 of the two-step impairment test). Entities will continue to have the option to perform a qualitative assessment to determine if a quantitative impairment test is necessary. Exelon, Generation, ComEd, PHI and DPL have goodwill as of December 31, 2018. This updated guidance is not currently expected to impact the Registrants’ financial reporting. The standard is effective January 1, 2020, with early adoption permitted, and must be applied on a prospective basis. Impairment of Financial Instruments (Issued June 2016). Provides for a new Current Expected Credit Loss (CECL) impairment model for specified financial instruments including loans, trade receivables, debt securities classified as held-to-maturity investments and net investments in leases recognized by a lessor. Under the new guidance, on initial recognition and at each reporting period, an entity is required to recognize an allowance that reflects the entity’s current estimate of credit losses expected to be incurred over the life of the financial instrument. The standard does not make changes to the existing impairment models for non-financial assets such as fixed assets, intangibles and goodwill. The standard will be effective January 1, 2020 (with early adoption as of January 1, 2019 permitted) and requires a modified retrospective transition approach through a cumulative-effect adjustment to retained earnings as of the beginning of the period of adoption. The Registrants are currently assessing the impacts of this standard. |
Earnings Per Share Earnings Per
Earnings Per Share Earnings Per Share (Policies) | 12 Months Ended |
Dec. 31, 2018 | |
Earnings Per Share [Abstract] | |
Earnings Per Share, Policy [Policy Text Block] | Basic earnings per share is computed by dividing net income attributable to common stockholders by the weighted average number of common shares outstanding during the period. Diluted earnings per share is computed by dividing net income attributable to common shareholders by the weighted average number of common shares outstanding, including the effect of issuing common stock assuming (i) stock options are exercised, and (ii) performance share awards and restricted stock awards are fully vested under the treasury stock method. |
Significant Accounting Polici_3
Significant Accounting Policies (Tables) | 12 Months Ended | |
Dec. 31, 2017 | Dec. 31, 2016 | |
Accounting Policies [Abstract] | ||
Cumulative Effect of New Accounting Pronouncement Adoption Revenue from Contract with Customer [Table Text Block] | . | . |
Variable Interest Entities (Tab
Variable Interest Entities (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Variable Interest Entity [Abstract] | |
Schedule of Variable Interest Entities | The carrying amounts and classification of the consolidated VIEs’ assets and liabilities included in the Registrants' consolidated financial statements at December 31, 2018 and 2017 are as follows: December 31, 2018 Exelon (a) Generation PHI (a) ACE Current assets $ 938 $ 931 $ 7 4 Noncurrent assets 9,071 9,045 26 19 Total assets $ 10,009 $ 9,976 $ 33 $ 23 Current liabilities $ 274 $ 252 $ 22 19 Noncurrent liabilities 3,280 3,233 47 40 Total liabilities $ 3,554 $ 3,485 $ 69 $ 59 December 31, 2017 Exelon (a) Generation PHI (a) ACE Current assets $ 662 $ 652 $ 10 $ 6 Noncurrent assets 9,317 9,286 31 23 Total assets $ 9,979 $ 9,938 $ 41 $ 29 Current liabilities $ 308 $ 272 $ 36 $ 32 Noncurrent liabilities 3,316 3,250 66 58 Total liabilities $ 3,624 $ 3,522 $ 102 $ 90 __________ (a) Includes certain purchase accounting adjustments not pushed down to the ACE standalone entity. The following tables present summary information about Exelon and Generation’s significant unconsolidated VIE entities: December 31, 2018 Commercial Agreement VIEs Equity Investment VIEs Total Total assets (a) $ 597 $ 472 $ 1,069 Total liabilities (a) 37 222 259 Exelon's ownership interest in VIE (a) — 223 223 Other ownership interests in VIE (a) 560 27 587 Registrants’ maximum exposure to loss: Carrying amount of equity method investments — 223 223 Contract intangible asset 7 — 7 Net assets pledged for Zion Station decommissioning (b) — — — December 31, 2017 Commercial Agreement VIEs Equity Investment VIEs Total Total assets (a) $ 625 $ 509 $ 1,134 Total liabilities (a) 37 228 265 Exelon's ownership interest in VIE (a) — 251 251 Other ownership interests in VIE (a) 588 30 618 Registrants’ maximum exposure to loss: Carrying amount of equity method investments — 251 251 Contract intangible asset 8 — 8 Net assets pledged for Zion Station decommissioning (b) 2 — 2 __________ (a) These items represent amounts on the unconsolidated VIE balance sheets, not in Exelon’s or Generation’s Consolidated Balance Sheets. These items are included to provide information regarding the relative size of the unconsolidated VIEs. (b) These items represent amounts in Exelon’s and Generation’s Consolidated Balance Sheets related to the asset sale agreement with ZionSolutions, LLC. The net assets pledged for Zion Station decommissioning includes gross pledged assets of $9 million and $39 million as of December 31, 2018 and December 31, 2017 , respectively; offset by payables to ZionSolutions LLC of $9 million and $37 million as of December 31, 2018 and December 31, 2017 , respectively. These items are included to provide information regarding the relative size of the ZionSolutions, LLC unconsolidated VIE. As of December 31, 2018 and 2017 , these assets and liabilities primarily consisted of the following: December 31, 2018 Exelon (a) Generation PHI (a) ACE Cash and cash equivalents $ 414 $ 414 $ — $ — Restricted cash and cash equivalents 66 62 4 4 Accounts receivable, net Customer 146 146 — — Other 23 23 — — Inventory Materials and supplies 212 212 — — Other current assets 52 49 3 — Total current assets 913 906 7 4 Property, plant and equipment, net 6,145 6,145 — — Nuclear decommissioning trust funds 2,351 2,351 — — Other noncurrent assets 258 232 26 19 Total noncurrent assets 8,754 8,728 26 19 Total assets $ 9,667 $ 9,634 $ 33 $ 23 Long-term debt due within one year $ 87 $ 66 $ 21 $ 18 Accounts payable 96 96 — — Accrued expenses 72 72 1 1 Unamortized energy contract liabilities 15 15 — — Other current liabilities 3 3 — — Total current liabilities 273 252 22 19 Long-term debt 1,072 1,025 47 40 Asset retirement obligations 2,160 2,160 — — Unamortized energy contract liabilities 1 1 — — Other noncurrent liabilities 42 42 — — Total noncurrent liabilities 3,275 3,228 47 40 Total liabilities $ 3,548 $ 3,480 $ 69 $ 59 __________ (a) Includes certain purchase accounting adjustments not pushed down to the ACE standalone entity. December 31, 2017 Exelon (a) Generation PHI (a) ACE Cash and cash equivalents $ 126 $ 126 $ — $ — Restricted cash and cash equivalents 64 58 6 6 Accounts receivable, net Customer 170 170 — — Other 25 25 — — Inventory Materials and supplies 205 205 — — Other current assets 45 41 4 — Total current assets 635 625 10 6 Property, plant and equipment, net 6,186 6,186 — — Nuclear decommissioning trust funds 2,502 2,502 — — Other noncurrent assets 274 243 31 23 Total noncurrent assets 8,962 8,931 31 23 Total assets $ 9,597 $ 9,556 $ 41 $ 29 Long-term debt due within one year $ 102 $ 67 $ 35 $ 31 Accounts payable 114 114 — — Accrued expenses 67 66 1 1 Unamortized energy contract liabilities 18 18 — — Other current liabilities 7 7 — — Total current liabilities 308 272 36 32 Long-term debt 1,154 1,088 66 58 Asset retirement obligations 2,035 2,035 — — Other noncurrent liabilities 121 121 — — Total noncurrent liabilities 3,310 3,244 66 58 Total liabilities $ 3,618 $ 3,516 $ 102 $ 90 __________ (a) Includes certain purchase accounting adjustments not pushed down to the ACE standalone entity. |
Revenue Recognition Revenue R_2
Revenue Recognition Revenue Recognition (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Revenue from Contract with Customer (All Registrants) [Abstract] | |
Contract with Customer, Asset and Liability [Table Text Block] | he following table provides a rollforward of the contract assets reflected in Exelon's and Generation's Consolidated Balance Sheets from January 1, 2018 to December 31, 2018 : Contract Assets Exelon and Generation Balance as of January 1, 2018 $ 283 Increases as a result of changes in the estimate of the stage of completion 50 Amounts reclassified to receivables (146 ) Balance at December 31, 2018 $ 187 The Utility Registrants do not have any contract assets. The following table provides a rollforward of the contract liabilities reflected in Exelon's and Generation's Consolidated Balance Sheet from January 1, 2018 to December 31, 2018 : Contract Liabilities Exelon Generation Balance as of January 1, 2018 $ 35 $ 35 Increases as a result of additional cash received or due 179 465 Amounts recognized into revenues (187 ) (458 ) Balance at December 31, 2018 $ 27 $ 42 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block] | 2019 2020 2021 2022 2023 and thereafter Total Exelon $ 631 $ 329 $ 119 $ 47 $ 138 $ 1,264 Generation 631 329 119 47 138 1,264 |
Regulatory Matters (Tables)
Regulatory Matters (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Regulated Operations [Abstract] | |
Public Utilities General Disclosures [Table Text Block] | Exelon ComEd (a) PECO BGE (b) PHI Pepco (c) DPL (c) ACE December 31, 2018 $ 65 $ 8 $ — $ 49 $ 8 $ 5 $ 3 $ — December 31, 2017 $ 69 $ 6 $ — $ 53 $ 10 $ 6 $ 4 $ — __________ (a) Reflects ComEd's unrecognized equity returns earned for ratemaking purposes on its electric distribution formula rate regulatory assets. (b) BGE's authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholders' investment on its AMI programs. (c) Pepco's and DPL's authorized amounts capitalized for ratemaking purposes relate to earnings on shareholders' investment on their respective AMI Programs and Energy Efficiency and Demand Response Programs. The earnings on energy efficiency are on Pepco DC and DPL DE programs only. |
Schedule of Regulatory Asset Impairments [Table Text Block] | For the year ended December 31, 2017 Exelon $ 35 ComEd 3 BGE 5 PHI 27 Pepco 14 DPL 6 ACE 7 On December 18, 2017, BGE filed for clarification and rehearing of FERC’s order, still seeking full recovery of its existing transmission-related income tax regulatory asset amounts, including those amounts that would have been previously amortized and recovered through rates had the transmission formula rate provided for such recovery. On February 27, 2018 (and updated on March 26, 2018), BGE submitted a letter to FERC advising that the lower federal corporate income tax rate effective January 1, 2018 provided for in the TCJA will be reflected in BGE’s annual formula rate update effective June 1, 2018, but that the deferred income tax benefits will not be passed back to customers unless BGE’s formula rate is revised to provide for pass back and recovery of transmission-related income tax-related regulatory liabilities and assets. On February 23, 2018 (as amended on July 9, 2018), ComEd, Pepco, DPL, and ACE each filed with FERC to revise their transmission formula rate mechanisms to facilitate passing back to customers ongoing annual TCJA tax savings and to permit recovery of transmission-related income tax regulatory assets, including those amounts that would have been previously amortized and recovered through rates had the transmission formula rate provided for such recovery. On September 7, 2018, FERC issued orders rejecting BGE’s December 18, 2017 request for rehearing and clarification and ComEd's, Pepco's, DPL's and ACE's February 23, 2018 (as amended on July 9, 2018) filings, again citing the lack of timeliness of the requests to recover amounts that would have been previously amortized, but indicating that ongoing recovery of certain transmission-related income tax regulatory assets would provide for a more accurate revenue requirement. The orders did not address the remittance of TCJA transmission-related income tax regulatory liabilities, but rather referenced FERC’s separate Notice of Inquiry of such amounts issued on March 15, 2018. On October 1, 2018, ComEd, BGE, Pepco, DPL, and ACE submitted new filings to recover ongoing non-TCJA amortization amounts and refund TCJA transmission-related income tax regulatory liabilities for the prospective period starting on October 1, 2018. FERC issued deficiency letters requesting additional information on November 21, 2018 and January 28, 2019. ComEd, BGE, Pepco, DPL, and ACE responded to the November 21, 2018 deficiency letter on November 29, 2018 but cannot predict the outcome of these FERC proceedings. If FERC ultimately rules that the future, ongoing non-TCJA amortization amounts are not recoverable, Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE would record additional charges to Income tax expense, which could be up to approximately $76 million , $51 million , $15 million , $10 million , $3 million , $5 million and $2 million , respectively, as of December 31, 2018. On October 9, 2018, ComEd, Pepco, DPL, and ACE sought rehearing of FERC's September 7, 2018 order, still seeking full recovery of their existing transmission-related income tax regulatory asset amounts, including those amounts that would have been previously amortized and recovered through rates had the transmission formula rate provided for such recovery. ComEd, Pepco, DPL, and ACE cannot predict the outcome of this rehearing request. On November 2, 2018, BGE filed an appeal of FERC’s September 7, 2018 order to the Court of Appeals for the D.C. Circuit. PJM Transmission Rate Design (All Registrants). On June 15, 2016, several parties, including the Utility Registrants, filed a proposed settlement with FERC to resolve outstanding issues related to cost responsibility for charges to transmission customers for certain transmission facilities that operate at or above 500 kV. The settlement included provisions for monthly credits or charges related to the periods prior to January 1, 2016 that are expected to be refunded or recovered through PJM wholesale transmission rates through December 2025. On May 31, 2018, FERC issued an order approving the settlement and directed PJM to adjust wholesale transmission rates within 30 days. Pursuant to the order, similar charges for the period January 1, 2016 through June 30, 2018 will also be refunded or recovered through PJM wholesale transmission rates over the subsequent 12-month period. PJM commenced billing the refunds and charges associated with this settlement in August 2018. The Utility Registrants expect to refund or recover these settlement amounts through prospective electric distribution customer rates. On July 2, 2018, several parties filed petitions for rehearing or clarification. Pursuant to the FERC approval of the settlement and the expected refund or recovery of the associated amounts from electric distribution customers, in the second quarter of 2018 and as adjusted in the third quarter of 2018, the Utility Registrants recorded the following payables to/receivables from PJM and related regulatory assets/liabilities. Generation recorded a $41 million net payable to PJM and a pre-tax charge within Purchased power and fuel expense in Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. PJM Receivable PJM Payable Regulatory Asset Regulatory Liability Exelon $ 220 $ 176 $ 136 $ 221 Generation (a) — 41 — — ComEd 122 — — 122 PECO 85 — — 85 BGE — 51 51 — PHI 13 84 85 14 Pepco — 84 84 — DPL 10 — — 10 ACE 3 — 1 4 __________ (a) |
Schedule of Regulatory Assets | The following tables provide information about the regulatory assets and liabilities of Exelon, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE as of December 31, 2018 and December 31, 2017 : December 31, 2018 Exelon ComEd PECO BGE PHI Pepco DPL ACE Regulatory assets Pension and other postretirement benefits $ 2,553 $ — $ — $ — $ — $ — $ — $ — Pension and other postretirement benefits - Merger related 1,266 — — — — — — — Deferred income taxes 414 — 404 — 10 10 — — AMI programs - Deployment Costs 202 — — 113 89 50 39 — AMI programs - Legacy Meters 328 136 24 48 120 90 30 — AMI programs - Post-test year costs 32 — — 32 — — — — Electric distribution formula rate annual reconciliations 158 158 — — — — — — Electric distribution formula rate significant one-time events 81 81 — — — — — — Energy efficiency costs 472 472 — — — — — — Fair value of long-term debt 702 — — — 569 — — — Fair value of PHI's unamortized energy contracts 561 — — — 561 — — — Asset retirement obligations 118 79 22 16 1 1 — — MGP remediation costs 326 309 17 — — — — — Renewable energy 249 249 — — — — — — Electric Energy and Natural Gas Costs 193 — 49 51 93 84 — 9 Transmission formula rate annual reconciliations 41 6 — 4 31 10 14 7 Energy efficiency and demand response programs 545 — 1 289 255 188 67 — Merger integration costs 42 — — 3 39 18 11 10 Under-recovered revenue decoupling 59 — — 2 57 57 — — Securitized stranded costs 50 — — — 50 — — 50 Removal costs 564 — — — 564 158 97 309 DC PLUG charge 159 — — — 159 159 — — Deferred storm costs 41 — — — 41 9 4 28 Other 303 110 24 17 162 79 28 13 Total regulatory assets 9,459 1,600 541 575 2,801 913 290 426 Less: current portion 1,222 293 81 177 489 270 59 40 Total noncurrent regulatory assets $ 8,237 $ 1,307 $ 460 $ 398 $ 2,312 $ 643 $ 231 $ 386 December 31, 2017 Exelon ComEd PECO BGE PHI Pepco DPL ACE Regulatory assets Pension and other postretirement benefits $ 2,455 $ — $ — $ — $ — $ — $ — $ — Pension and other postretirement benefits - Merger related 1,393 — — — — — — — Deferred income taxes 306 — 297 — 9 9 — — AMI programs - Deployment costs 385 — — 129 101 58 43 — AMI programs - Legacy meters 223 155 36 53 134 100 34 — AMI programs - Post-test year costs 32 — — 32 — — — — Electric distribution formula rate annual reconciliations 186 186 — — — — — — Electric distribution formula rate significant one-time events 58 58 — — — — — — Energy efficiency costs 166 166 — — — — — — Fair value of long-term debt 758 — — — 619 — — — Fair value of PHI's unamortized energy contracts 750 — — — 750 — — — Asset retirement obligations 109 73 22 14 — — — — MGP remediation costs 295 273 22 — — — — — Renewable energy 258 256 — — 2 — 1 1 Electric energy and natural gas costs 47 — 1 16 30 8 7 15 Transmission formula rate annual reconciliations 35 6 — 7 22 3 8 11 Energy efficiency and demand response programs 596 — 1 285 310 229 81 — Merger integration costs 45 — — 6 39 20 10 9 Under-recovered revenue decoupling 55 — — 14 41 38 3 — Securitized stranded costs 79 — — — 79 — — 79 Removal costs 529 — — — 529 150 93 286 DC PLUG charge 190 — — — 190 190 — — Deferred storm costs 27 — — — 27 7 5 15 Other 311 106 31 15 165 79 29 14 Total regulatory assets 9,288 1,279 410 571 3,047 891 314 430 Less: current portion 1,267 225 29 174 554 213 69 71 Total noncurrent regulatory assets $ 8,021 $ 1,054 $ 381 $ 397 $ 2,493 $ 678 $ 245 $ 359 December 31, 2017 Exelon ComEd PECO BGE PHI Pepco DPL ACE Regulatory liabilities Deferred income taxes $ 5,241 $ 2,479 $ — $ 1,032 $ 1,730 $ 809 $ 510 $ 411 Nuclear decommissioning 3,064 2,528 536 — — — — — Removal costs 1,573 1,338 — 105 130 20 110 — Electric Energy and Natural Gas Costs 111 47 60 — 4 — 1 3 Other 399 185 94 26 64 3 14 8 Total regulatory liabilities 10,388 6,577 690 1,163 1,928 832 635 422 Less: current portion 523 249 141 62 56 3 42 11 Total noncurrent regulatory liabilities $ 9,865 $ 6,328 $ 549 $ 1,101 $ 1,872 $ 829 $ 593 $ 411 |
Schedule of Regulatory Liabilities | December 31, 2017 Exelon ComEd PECO BGE PHI Pepco DPL ACE Regulatory liabilities Deferred income taxes $ 5,241 $ 2,479 $ — $ 1,032 $ 1,730 $ 809 $ 510 $ 411 Nuclear decommissioning 3,064 2,528 536 — — — — — Removal costs 1,573 1,338 — 105 130 20 110 — Electric Energy and Natural Gas Costs 111 47 60 — 4 — 1 3 Other 399 185 94 26 64 3 14 8 Total regulatory liabilities 10,388 6,577 690 1,163 1,928 832 635 422 Less: current portion 523 249 141 62 56 3 42 11 Total noncurrent regulatory liabilities $ 9,865 $ 6,328 $ 549 $ 1,101 $ 1,872 $ 829 $ 593 $ 411 December 31, 2018 Exelon ComEd PECO BGE PHI Pepco DPL ACE Regulatory liabilities Deferred income taxes $ 5,228 $ 2,394 $ — $ 1,132 $ 1,702 $ 798 $ 510 $ 394 Nuclear decommissioning 2,606 2,217 389 — — — — — Removal costs 1,547 1,368 — 52 127 20 107 — Electric Energy and Natural Gas Costs 294 137 132 6 19 — 18 1 Other 528 227 75 79 100 11 30 25 Total regulatory liabilities 10,203 6,343 596 1,269 1,948 829 665 420 Less: current portion 644 293 175 77 84 7 59 18 Total noncurrent regulatory liabilities $ 9,559 $ 6,050 $ 421 $ 1,192 $ 1,864 $ 822 $ 606 $ 402 |
Mergers, Acquisitions and Dis_2
Mergers, Acquisitions and Dispositions (Tables) | 12 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2016 | |
Business Combinations [Abstract] | ||
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block] | The following table summarizes the final acquisition-date fair value of the consideration transferred and the assets and liabilities assumed for the FitzPatrick acquisition by Generation: Cash paid for purchase price $ 110 Cash paid for net cost reimbursement 125 Nuclear fuel transfer 54 Total consideration transferred $ 289 Identifiable assets acquired and liabilities assumed Current assets $ 60 Property, plant and equipment 298 Nuclear decommissioning trust funds 807 Other assets (a) 114 Total assets $ 1,279 Current liabilities $ 6 Nuclear decommissioning ARO 444 Pension and OPEB obligations 33 Deferred income taxes 149 Spent nuclear fuel obligation 110 Other liabilities 15 Total liabilities $ 757 Total net identifiable assets, at fair value $ 522 Bargain purchase gain (after-tax) $ 233 _________ (a) Includes a $110 million asset associated with a contractual right to reimbursement from the New York Power Authority (NYPA), a prior owner of FitzPatrick, associated with the DOE one-time fee obligation. See Note 22 - Commitments and Contingencies for additional information regarding SNF obligations to the DOE. | |
Business Combination, Separately Recognized Transactions [Table Text Block] | The following amounts represent total commitment costs for Exelon, PHI, Pepco, DPL and ACE that have been recorded since the merger date: Expected Payment Period Successor Description Exelon PHI Pepco DPL ACE Rate credits 2016 - 2021 $ 259 $ 264 $ 91 $ 72 $ 101 Energy efficiency 2016 - 2021 117 — — — — Charitable contributions 2016 - 2026 50 50 28 12 10 Delivery system modernization Q2 2017 22 — — — — Green sustainability fund Q2 2017 14 — — — — Workforce development 2016 - 2020 17 — — — — Other 29 6 1 5 — Total commitments $ 508 $ 320 $ 120 $ 89 $ 111 Remaining commitments as of December 31, 2018 $ 128 $ 92 $ 73 $ 12 $ 7 | |
Business Acquisition, Pro Forma Information [Table Text Block] | The current impact of PHI, including its unregulated businesses, in Exelon's Consolidated Statements of Operations and Comprehensive Income includes Operating revenues and Net Income (Loss) as follows: For the Years Ended December 31, 2018 2017 2016 Operating Revenues 4,670 4,829 3,785 Net Income (Loss) 453 364 (66 ) | |
Restructuring and Related Costs [Table Text Block] | For the periods ended December 31, 2018 , 2017 and 2016 , the Registrants have recognized costs to achieve the PHI merger as follows: For the Year Ended December 31, Acquisition, Integration and Financing Costs (a) 2018 2017 2016 Exelon $ 7 $ 16 $ 143 Generation 5 22 37 ComEd (b) — 1 (6 ) PECO 1 4 5 BGE (b) 1 4 (1 ) Pepco (b) — (6 ) 28 DPL (b) — (7 ) 20 ACE (b) — (6 ) 19 Successor Predecessor For the Year Ended December 31, March 24, 2016 to December 31, 2016 January 1, 2016 to Acquisition, Integration and Financing Costs (a) 2018 2017 PHI (b) $ — $ (18 ) $ 69 $ 29 ______________ (a) The costs incurred are classified primarily within Operating and maintenance expense in the Registrants’ respective Consolidated Statements of Operations and Comprehensive Income, with the exception of the financing costs, which are included within Interest expense. Costs do not include merger commitments discussed above. (b) For the year ended December 31, 2017 , includes deferrals of previously incurred integration costs as regulatory assets of $24 million , $8 million , $8 million , and $8 million at PHI, Pepco, DPL and ACE, respectively. For the year ended December 31, 2016 , includes deferrals of previously incurred integration costs as regulatory assets of $8 million , $6 million , $11 million and $4 million at ComEd, BGE, Pepco and DPL, respectively. For the Successor period March 24, 2016 to December 31, 2016 , includes deferrals of previously incurred integration costs as regulatory assets of $16 million at PHI. See Note 4 - Regulatory Matters for additional information. | For the year ended December 31, 2016 , the Registrants recorded the following severance costs associated with the identified job reductions within Operating and maintenance expense in their Consolidated Statements of Operations and Comprehensive Income: Severance Benefits Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Severance costs (a) $ 57 $ 9 $ 2 $ 1 $ 1 $ 44 $ 21 $ 13 $ 10 (a) The amounts above for Generation, ComEd, PECO, BGE, Pepco, DPL, and ACE include $8 million , $2 million , $1 million , $1 million , $20 million , $12 million and $10 million , respectively, for amounts billed by BSC and/or PHISCO through intercompany allocations. |
Business Acquisition, Pro Forma Information, Nonrecurring Adjustments [Table Text Block] | The unaudited pro-forma financial information has been presented for illustrative purposes only and is not necessarily indicative of results of operations that would have been achieved had the merger events taken place on the dates indicated, or future consolidated results of operations of the combined company. Year Ended December 31, 2016 (a) 2015 (b) Total operating revenues $ 32,342 $ 33,823 Net income attributable to common shareholders 1,562 2,618 Basic earnings per share $ 1.69 $ 2.85 Diluted earnings per share 1.69 2.84 ______________ (a) The amounts above exclude non-recurring costs directly related to the merger of $680 million and intercompany revenue of $171 million for the year ended December 31, 2016 . (b) The amounts above exclude non-recurring costs directly related to the merger of $92 million and intercompany revenue of $559 million for the year ended December 31, 2015 . |
Property, Plant, and Equipment
Property, Plant, and Equipment (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Property, Plant and Equipment [Line Items] | |
Property, Plant and Equipment | Exelon The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-90 $ 53,090 $ 49,506 Electric—generation 1-56 29,170 29,019 Gas—transportation and distribution 5-90 5,530 5,050 Common—electric and gas 5-75 1,627 1,447 Nuclear fuel (a) 1-8 5,957 6,420 Construction work in progress N/A 3,377 2,825 Other property, plant and equipment (b) 1-50 858 999 Total property, plant and equipment 99,609 95,266 Less: accumulated depreciation (c) 22,902 21,064 Property, plant and equipment, net $ 76,707 $ 74,202 __________ (a) Includes nuclear fuel that is in the fabrication and installation phase of $1,004 million and $1,196 million at December 31, 2018 and 2017 , respectively. (b) Includes Generation’s buildings under capital lease with a net carrying value of $5 million and $7 million at December 31, 2018 and 2017 , respectively. The original cost basis of the buildings was $47 million as of both December 31, 2018 and 2017 , and total accumulated amortization was $42 million and $40 million , as of December 31, 2018 and 2017 , respectively. Also includes ComEd’s buildings under capital lease with a net carrying value at both December 31, 2018 and 2017 , of $7 million . The original cost basis of the buildings was $8 million and total accumulated amortization was $1 million as of both December 31, 2018 and 2017 . Includes land held for future use and non-utility property at ComEd, PECO, BGE, Pepco, DPL and ACE of $39 million , $19 million , $25 million , $61 million , $17 million and $28 million , respectively, at December 31, 2018 . (c) Includes accumulated amortization of nuclear fuel in the reactor core at Generation of $2,969 million and $3,159 million as of December 31, 2018 and 2017 , respectively. Generation The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—generation 1-56 $ 29,170 $ 29,019 Nuclear fuel (a) 1-8 5,957 6,420 Construction work in progress N/A 997 838 Other property, plant and equipment (b) 1-8 63 57 Total property, plant and equipment 36,187 36,334 Less: accumulated depreciation (c) 12,206 11,428 Property, plant and equipment, net $ 23,981 $ 24,906 __________ (a) Includes nuclear fuel that is in the fabrication and installation phase of $1,004 million and $1,196 million at December 31, 2018 and 2017 , respectively. (b) Includes buildings under capital lease with a net carrying value of $5 million and $7 million at December 31, 2018 and 2017 , respectively. The original cost basis of the buildings was $47 million as of both December 31, 2018 and 2017 , and total accumulated amortization was $42 million and $40 million , as of December 31, 2018 and 2017 , respectively. (c) Includes accumulated amortization of nuclear fuel in the reactor core of $2,969 million and $3,159 million as of December 31, 2018 and 2017 , respectively. ComEd The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-80 $ 25,991 $ 24,423 Construction work in progress N/A 705 517 Other property, plant and equipment (a), (b) 35-50 46 52 Total property, plant and equipment 26,742 24,992 Less: accumulated depreciation 4,684 4,269 Property, plant and equipment, net $ 22,058 $ 20,723 __________ (a) Includes buildings under capital lease with a net carrying value at both December 31, 2018 and 2017 of $7 million . The original cost basis of the buildings was $8 million and total accumulated amortization was $1 million as of both December 31, 2018 and 2017 . (b) Represents land held for future use and non-utility property. PECO The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-65 $ 8,359 $ 7,975 Gas—transportation and distribution 5-70 2,694 2,504 Common—electric and gas 5-50 756 710 Construction work in progress N/A 343 254 Other property, plant and equipment (a) 50 19 21 Total property, plant and equipment 12,171 11,464 Less: accumulated depreciation 3,561 3,411 Property, plant and equipment, net $ 8,610 $ 8,053 __________ (a) Represents land held for future use and non-utility property. BGE The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-90 $ 7,951 $ 7,464 Gas—distribution 5-90 2,630 2,379 Common—electric and gas 5-40 860 771 Construction work in progress N/A 410 367 Other property, plant and equipment (a) 20 25 26 Total property, plant and equipment 11,876 11,007 Less: accumulated depreciation 3,633 3,405 Property, plant and equipment, net $ 8,243 $ 7,602 __________ (a) Represents plant held for future use and non-utility property. PHI The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average 2018 2017 Asset Category Electric—transmission and distribution 5-75 $ 12,664 $ 11,517 Gas—distribution 5-75 486 449 Common—electric and gas 5-75 126 82 Construction work in progress N/A 912 835 Other property, plant and equipment (a) 3-43 99 102 Total property, plant and equipment 14,287 12,985 Less: accumulated depreciation 841 487 Property, plant and equipment, net $ 13,446 $ 12,498 __________ (a) Represents plant held for future use and non-utility property. Pepco The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-75 $ 9,217 $ 8,646 Construction work in progress N/A 536 473 Other property, plant and equipment (a) 25-33 61 59 Total property, plant and equipment 9,814 9,178 Less: accumulated depreciation 3,354 3,177 Property, plant and equipment, net $ 6,460 $ 6,001 __________ (a) Represents plant held for future use and non-utility property. DPL The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-70 $ 4,195 $ 3,875 Gas—distribution 5-75 651 614 Common—electric and gas 5-75 136 117 Construction work in progress N/A 151 205 Other property, plant and equipment (a) 10-43 17 15 Total property, plant and equipment 5,150 4,826 Less: accumulated depreciation 1,329 1,247 Property, plant and equipment, net $ 3,821 $ 3,579 __________ (a) Represents plant held for future use and non-utility property. ACE The following table presents a summary of property, plant and equipment by asset category as of December 31, 2018 and 2017 : Average Service Life (years) 2018 2017 Asset Category Electric—transmission and distribution 5-60 $ 3,866 $ 3,607 Construction work in progress N/A 209 138 Other property, plant and equipment (a) 13-15 28 27 Total property, plant and equipment 4,103 3,772 Less: accumulated depreciation 1,137 1,066 Property, plant and equipment, net $ 2,966 $ 2,706 __________ (a) Represents plant held for future use and non-utility property. |
Property Plant And Equipment Average Service Life Percentage By Asset Category Table | Exelon The following table presents the annual depreciation provisions as a percentage of average service life for each asset category. Average Service Life Percentage by Asset Category 2018 2017 2016 Electric—transmission and distribution 2.73 % 2.75 % 2.73 % Electric—generation (a) 5.37 % 4.36 % 5.94 % Gas 2.07 % 2.10 % 2.17 % Common—electric and gas 6.98 % 7.05 % 7.41 % __________ (a) See Note 8 — Early Plant Retirements for additional information on the accelerated net depreciation and amortization of Clinton, Quad Cities, Oyster Creek and TMI. PECO The following table presents the annual depreciation provisions as a percentage of average service life for each asset category. Average Service Life Percentage by Asset Category 2018 2017 2016 Electric—transmission and distribution 2.35 % 2.37 % 2.32 % Gas 1.90 % 1.89 % 1.82 % Common—electric and gas 5.44 % 5.47 % 5.11 % BGE The following table presents the annual depreciation provisions as a percentage of average service life for each asset category. Average Service Life Percentage by Asset Category 2018 2017 2016 Electric—transmission and distribution 2.61 % 2.58 % 2.56 % Gas 2.36 % 2.33 % 2.45 % Common—electric and gas 8.50 % 8.64 % 9.45 % PHI The following table presents the annual depreciation provisions as a percentage of average service life for each asset category. Average Service Life Percentage by Asset Category 2018 2017 2016 Electric—transmission and distribution 2.61 % 2.63 % 2.52 % Gas 1.59 % 2.07 % 2.57 % Common—electric and gas 6.30 % 6.50 % 8.12 % DPL The following table presents the annual depreciation provisions as a percentage of average service life for each asset category. Average Service Life Percentage by Asset Category 2018 2017 2016 Electric—transmission and distribution 2.77 % 2.75 % 2.49 % Gas 1.59 % 2.07 % 2.57 % Common—electric and gas 3.70 % 4.14 % 4.99 % |
Schedule Of Capitalized Software | Capitalized Software Costs (All Registrants) The following tables presents net unamortized capitalized software costs and amortization of capitalized software costs by year. Net unamortized software costs Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE December 31, 2018 $ 810 $ 164 $ 206 $ 98 $ 166 $ 165 $ 26 $ 21 $ 14 December 31, 2017 834 173 227 111 179 133 2 1 1 Amortization of capitalized software costs Exelon Generation ComEd PECO BGE Pepco DPL ACE 2018 $ 282 $ 78 $ 79 $ 37 $ 48 $ 2 $ 2 $ 1 2017 270 73 73 39 46 — — — 2016 255 72 62 33 44 — — — Successor Predecessor PHI For the year ended December 31, 2018 For the year ended December 31, 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Amortization of capitalized software costs $ 33 $ 34 $ 29 $ 8 |
Schedule Of Capitalized Interest And AFUDC | Capitalized Interest and AFUDC (All Registrants) The following table summarizes total incurred interest, capitalized interest and credits to AFUDC by year: Exelon Generation ComEd PECO BGE Pepco DPL ACE 2018 Total incurred interest (a) $ 1,695 $ 464 $ 377 $ 141 $ 130 $ 162 $ 62 $ 68 Capitalized interest 31 31 — — — — — — Credits to AFUDC debt and equity 109 — 30 12 24 34 4 4 2017 Total incurred interest (a) $ 1,658 $ 502 $ 369 $ 130 $ 111 $ 133 $ 54 $ 64 Capitalized interest 63 63 — — — — — — Credits to AFUDC debt and equity 108 — 20 12 22 34 10 9 2016 Total incurred interest (a) $ 1,678 $ 472 $ 469 $ 127 $ 114 $ 137 $ 52 $ 65 Capitalized interest 108 107 — — — — — — Credits to AFUDC debt and equity 98 — 22 11 30 29 7 9 Successor Predecessor PHI For the year ended December 31, 2018 For the year ended December 31, 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Total incurred interest (a) $ 305 $ 263 $ 207 $ 68 Credits to AFUDC debt and equity 44 54 35 10 __________ (a) Includes interest expense to affiliates. |
Early Plant Retirements Early_2
Early Plant Retirements Early Plant Retirements (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Implications of Potential Early Plant Retirements [Abstract] | |
Schedule of Other Operating Cost and Expense, by Component [Table Text Block] | The total annual impact of these charges by year are summarized in the table below. Income statement expense (pre-tax) 2018 (a) 2017 (b) 2016 (c) Depreciation and Amortization Accelerated depreciation (d) $ 539 $ 250 $ 712 Accelerated nuclear fuel amortization 57 12 60 Operating and Maintenance One-time charges (e,f) 32 77 26 Change in ARO accretion, net of any contractual offset (g) — — 2 Contractual offset for ARC depreciation (g) — — (86 ) Total $ 628 $ 339 $ 714 _________ (a) Reflects incremental accelerated depreciation for TMI and Oyster Creek. The Oyster Creek year-to-date amounts are from February 2, 2018 through September 17, 2018. (b) Reflects incremental charges for TMI including incremental accelerated depreciation and amortization from May 30, 2017 through December 31, 2017. (c) Reflects incremental charges for Clinton and Quad Cities including incremental accelerated depreciation and amortization from June 2, 2016 through December 6, 2016. In December 2016, as a result of reversing its retirement decision for Clinton and Quad Cities, Exelon and Generation updated the expected economic useful life for both facilities, to 2027 for Clinton, commensurate with the end of the Illinois ZES, and to 2032 for Quad Cities, the end of its current operating license. Depreciation was therefore adjusted beginning December 7, 2016, to reflect these extended useful life estimates. (d) Reflects incremental accelerated depreciation of plant assets, including any ARC. (e) Primarily includes materials and supplies inventory reserve adjustments, employee related costs and CWIP impairments. Excludes the charge to Operating and maintenance expense from the ARO remeasurement due to the announced sale of Oyster Creek. See Note 5 — Mergers, Acquisitions and Dispositions for additional information. (f) In June 2016, as a result of the retirement decision for Clinton and Quad Cities, Exelon and Generation recognized one-time charges of $146 million . In December 2016, as a result of reversing its retirement decision for Clinton and Quad Cities, Exelon and Generation reversed approximately $120 million of these one-time charges initially recorded in June 2016. (g) For Quad Cities based on the regulatory agreement with the ICC, decommissioning-related activities are offset within Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. The offset results in an equal adjustment to the noncurrent payables to ComEd at Generation and an adjustment to the regulatory liabilities at ComEd. Likewise, ComEd has recorded an equal noncurrent affiliate receivable from Generation and corresponding regulatory liability. |
Implications of Potential Early Plant Retirement on Balance Sheet [Table Text Block] | The following table provides the balance sheet amounts as of December 31, 2018 for Generation’s significant assets and liabilities associated with the Mystic Units 8 and 9 and Everett Marine Terminal assets that would potentially be impacted by a decision to permanently cease generation operations. December 31, 2018 Asset Balances Materials and supplies inventory $ 30 Fuel inventory 20 Completed plant, net 901 Construction work in progress 9 Liability Balances Asset retirement obligation (1 ) December 31, 2018 Asset Balances Materials and supplies inventory $ 45 Nuclear fuel inventory, net 118 Completed plant, net 538 Construction work in progress 44 Liability Balances Asset retirement obligation (395 ) NRC License Renewal Term 2036 (unit 1) 2040 (unit 2) |
Jointly Owned Electric Utilit_2
Jointly Owned Electric Utility Plant (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Public Utilities, Property, Plant and Equipment [Abstract] | |
Schedule of Jointly Owned Utility Plants | Exelon's, Generation's, PECO's, BGE's, Pepco's, DPL's and ACE's undivided ownership interests in jointly owned electric plants and transmission facilities at December 31, 2018 and 2017 were as follows: Nuclear Generation Fossil-Fuel Generation Transmission Other Quad Cities Peach Bottom Salem (a) Nine Mile Point Unit 2 Wyman PA (b) NJ/ DE (c) Other (d) Operator Generation Generation PSEG Generation FP&L First PSEG/ DPL various Ownership interest 75.00 % 50.00 % 42.59 % 82.00 % 5.89 % various various various Exelon’s share at December 31, 2018: Plant (e) $ 1,131 $ 1,451 $ 648 $ 910 $ 4 $ 28 $ 103 $ 15 Accumulated depreciation (e) 587 523 227 126 3 16 53 13 Construction work in progress 13 15 44 56 — 1 — — Exelon’s share at December 31, 2017: Plant (e) $ 1,074 $ 1,417 $ 631 $ 839 $ 3 $ 27 $ 102 $ 15 Accumulated depreciation (e) 550 461 205 97 3 15 52 13 Construction work in progress 35 18 33 55 — — — — __________ (a) Generation also owns a proportionate share in the fossil-fuel combustion turbine at Salem, which is fully depreciated. The gross book value was $3 million at December 31, 2018 and 2017 . (b) PECO, BGE, Pepco, DPL and ACE own a 22% , 7% , 27% , 9% and 8% share, respectively, in 127 miles of 500 kV lines located in Pennsylvania as well as a 20.72% , 10.56% , 9.72% , 3.72% and 3.83% share, respectively, of a 500 kV substation immediately outside of the Conemaugh fossil-generating station which supplies power to the 500 kV lines including, but not limited to, the lines noted above. (c) PECO, DPL and ACE own a 42.55% , 1% and 13.9% share, respectively in 151.3 miles of 500 kV lines located in New Jersey and of the Salem generating plant substation. PECO, DPL and ACE also own a 42.55% , 7.45% and 7.45% share, respectively, in 2.5 miles of 500 kV line located over the Delaware River. ACE also has a 21.78% share in a 500 kV New Freedom Switching substation. (d) Generation, DPL and ACE own a 44.24% , 11.91% and 4.83% share, respectively in assets located at Merrill Creek Reservoir located in New Jersey. Pepco, DPL and ACE own a 11.9% , 7.4% and 6.6% share, respectively, in Valley Forge Corporate Center. (e) Excludes asset retirement costs and general plant. |
Intangible Assets (Tables)
Intangible Assets (Tables) | 12 Months Ended | |
Dec. 31, 2018 | ||
Finite-Lived Intangible Assets [Line Items] | ||
Schedule Of Goodwill | Exelon’s, ComEd’s and PHI's gross amount of goodwill, accumulated impairment losses and carrying amount of goodwill for the years ended December 31, 2018 and 2017 were as follows: Balance at January 1, 2017 Impairment losses Balance at December 31, 2017 Impairment losses Balance at December 31, 2018 Exelon Gross amount $ 8,660 $ — $ 8,660 $ — $ 8,660 Accumulated impairment loss 1,983 — 1,983 — 1,983 Carrying amount 6,677 — 6,677 — 6,677 ComEd (a) Gross amount 4,608 — 4,608 — 4,608 Accumulated impairment loss 1,983 — 1,983 — 1,983 Carrying amount 2,625 — 2,625 — 2,625 PHI (b) Gross amount 4,005 — 4,005 — 4,005 Carrying amount 4,005 — 4,005 — 4,005 __________ (a) Reflects goodwill recorded in 2000 from the PECO/Unicom merger (predecessor parent company of ComEd). | [1],[2] |
Schedule of Finite-Lived Intangible Assets | Exelon’s, Generation’s, ComEd’s and PHI's other intangible assets and liabilities, included in Unamortized energy contract assets and liabilities and Other deferred debits and other assets in their Consolidated Balance Sheets, consisted of the following as of December 31, 2018 and 2017 : December 31, 2018 December 31, 2017 Gross Accumulated Amortization Net Gross Accumulated Amortization Net Generation Unamortized Energy Contracts (b) 1,957 (1,588 ) 369 1,938 (1,574 ) 364 Customer Relationships 325 (162 ) 163 305 (133 ) 172 Trade Name 243 (171 ) 72 243 (148 ) 95 ComEd Chicago Settlement Agreements (c) 162 (148 ) 14 162 (141 ) 21 PHI Unamortized Energy Contracts (b) (1,515 ) 954 (561 ) (1,515 ) 766 (749 ) Exelon Corporate Software License (a) 95 (34 ) 61 95 (25 ) 70 Exelon $ 1,267 $ (1,149 ) $ 118 $ 1,228 $ (1,255 ) $ (27 ) __________ (a) On May 31, 2015, Exelon entered into a long-term software license agreement. Exelon is required to make payments starting August 2015 through May 2024. The intangible asset recognized as a result of these payments is being amortized on a straight-line basis over the contract term. (b) Includes unamortized energy contract assets and liabilities in Exelon's, Generations and PHI's Consolidated Balance Sheets. (c) In March 1999 and February 2003, ComEd entered into separate agreements with the City of Chicago and Midwest Generation, LLC. Under the terms of the settlement, ComEd agreed to make payments to the City of Chicago. The intangible asset recognized as a result of the settlement agreement is being amortized ratably over the remaining term of the City of Chicago franchise agreement. | |
Schedule of Finite-Lived Intangible Assets, Future Amortization Expense [Table Text Block] | The following table summarizes the estimated future amortization expense related to intangible assets and liabilities as of December 31, 2018 : For the Years Ending December 31, Exelon Generation ComEd PHI 2019 $ (32 ) $ 70 $ 7 $ (119 ) 2020 (20 ) 78 7 (115 ) 2021 (4 ) 78 — (92 ) 2022 (23 ) 56 — (89 ) 2023 (21 ) 50 — (81 ) | |
Schedule Of Finite-Lived Intangible Assets Amortization Expense | The following table summarizes the amortization expense related to intangible assets and liabilities for each of the years ended December 31, 2018 , 2017 and 2016 : For the Years Ended December 31, Exelon (a)(b) Generation (a) ComEd PHI (b) 2018 $ (109 ) $ 63 $ 7 $ (188 ) 2017 (237 ) 83 7 (336 ) 2016 (336 ) 79 7 (430 ) __________ (a) At Exelon and Generation, amortization of unamortized energy contracts totaling $14 million , $35 million and $35 million for the years ended December 31, 2018 , 2017 and 2016 , respectively, was recorded in Operating revenues or Purchased power and fuel expense in their Consolidated Statements of Operations and Comprehensive Income | |
Schedule of Alternative or Renewable Energy Credits [Table Text Block] | The following table summarizes the current and noncurrent Renewable and Alternative Energy Credits as of December 31, 2018 and 2017 : As of December 31, 2018 Exelon Generation PECO PHI DPL ACE Current AEC's $ 2 $ — $ 2 $ — $ — $ — Current REC's 279 270 — 9 8 1 Noncurrent REC's 52 52 — — — — As of December 31, 2017 Exelon Generation PECO PHI DPL ACE Current AEC's $ 1 $ — $ 1 $ — $ — $ — Current REC's 321 312 — 9 8 1 Noncurrent REC's 27 27 — — — — | |
[1] | (b)Reflects goodwill recorded in 2016 from the PHI merger. | |
[2] | Reflects goodwill recorded in 2000 from the PECO/Unicom merger (predecessor parent company of ComEd). |
Fair Value of Financial Asset_2
Fair Value of Financial Assets and Liabilities (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Fair Value Disclosures [Abstract] | |
Fair value of financial liabilities recorded at the carrying amount | The following tables present the carrying amounts and fair values of the Registrants’ short-term liabilities, long-term debt, SNF obligation, and trust preferred securities (long-term debt to financing trusts or junior subordinated debentures) as of December 31, 2018 and 2017 : Exelon December 31, 2018 Carrying Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 714 $ — $ 714 $ — $ 714 Long-term debt (including amounts due within one year) (a) 35,424 — 33,711 2,158 35,869 Long-term debt to financing trusts (b) 390 — — 400 400 SNF obligation 1,171 — 949 — 949 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 929 $ — $ 929 $ — $ 929 Long-term debt (including amounts due within one year) (a) 34,264 — 34,735 1,970 36,705 Long-term debt to financing trusts (b) 389 — — 431 431 SNF obligation 1,147 — 936 — 936 Generation December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 8,793 $ — $ 7,467 $ 1,443 $ 8,910 SNF obligation 1,171 — 949 — 949 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 2 $ — $ 2 $ — $ 2 Long-term debt (including amounts due within one year) (a) 8,990 — 7,839 1,673 9,512 SNF obligation 1,147 — 936 — 936 ComEd December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 8,101 $ — $ 8,390 $ — $ 8,390 Long-term debt to financing trusts (b) 205 — — 209 209 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 7,601 $ — $ 8,418 $ — $ 8,418 Long-term debt to financing trusts (b) 205 — — 227 227 PECO December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 3,084 $ — $ 3,157 $ 50 $ 3,207 Long-term debt to financing trusts 184 — — 191 191 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 2,903 $ — $ 3,194 $ — $ 3,194 Long-term debt to financing trusts 184 — — 204 204 BGE December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 35 $ — $ 35 $ — $ 35 Long-term debt (including amounts due within one year) (a) 2,876 — 2,950 — 2,950 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 77 $ — $ 77 $ — $ 77 Long-term debt (including amounts due within one year) (a) 2,577 — 2,825 — 2,825 PHI December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 179 $ — $ 179 $ — $ 179 Long-term debt (including amounts due within one year) (a) 6,259 — 5,436 665 6,101 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 350 $ — $ 350 $ — $ 350 Long-term debt (including amounts due within one year) (a) 5,874 — 5,722 297 6,019 Pepco December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 40 $ — $ 40 $ — $ 40 Long-term debt (including amounts due within one year) (a) 2,719 — 2,901 196 3,097 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 26 $ — $ 26 $ — $ 26 Long-term debt (including amounts due within one year) (a) 2,540 — 3,114 9 3,123 DPL December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Long-term debt (including amounts due within one year) (a) $ 1,494 $ — $ 1,303 $ 193 $ 1,496 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 216 $ — $ 216 $ — $ 216 Long-term debt (including amounts due within one year) (a) 1,300 — 1,393 — 1,393 ACE December 31, 2018 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 139 $ — $ 139 $ — $ 139 Long-term debt (including amounts due within one year) (a) 1,188 — 987 275 1,262 December 31, 2017 Carrying Amount Fair Value Level 1 Level 2 Level 3 Total Short-term liabilities $ 108 $ — $ 108 $ — $ 108 Long-term debt (including amounts due within one year) (a) 1,121 — 949 288 1,237 __________ (a) Includes unamortized debt issuance costs which are not fair valued of $216 million , $51 million , $63 million , $23 million , $18 million , $14 million , $34 million , $12 million and $7 million for Exelon, Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE respectively, as of December 31, 2018 . Includes unamortized debt issuance costs which are not fair valued of $201 million , $60 million , $52 million , $17 million , $17 million , $6 million , $32 million , $11 million and $5 million for Exelon, Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE respectively, as of December 31, 2017 . (b) Includes unamortized debt issuance costs which are not fair valued of $0 million and $1 million for Exelon and ComEd, respectively, as of December 31, 2018 . Includes unamortized debt issuance costs which are not fair valued of $1 million and $1 million for Exelon and ComEd, respectively, as of December 31, 2017 . |
Assets and liabilities measured and recorded at fair value on recurring basis | The following tables present assets and liabilities measured and recorded at fair value in Exelon's and Generation’s Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of December 31, 2018 and 2017 : Generation Exelon As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Assets Cash equivalents (a) $ 581 $ — $ — $ — $ 581 $ 1,243 $ — $ — $ — $ 1,243 NDT fund investments Cash equivalents (b) 252 86 — — 338 252 86 — — 338 Equities 2,918 1,591 — 1,381 5,890 2,918 1,591 — 1,381 5,890 Fixed income Corporate debt — 1,593 230 — 1,823 — 1,593 230 — 1,823 U.S. Treasury and agencies 2,081 99 — — 2,180 2,081 99 — — 2,180 Foreign governments — 50 — — 50 — 50 — — 50 State and municipal debt — 149 — — 149 — 149 — — 149 Other (c) — 30 — 846 876 — 30 — 846 876 Fixed income subtotal 2,081 1,921 230 846 5,078 2,081 1,921 230 846 5,078 Middle market lending — — 313 367 680 — — 313 367 680 Private equity — — — 329 329 — — — 329 329 Real estate — — — 510 510 — — — 510 510 NDT fund investments subtotal (d) 5,251 3,598 543 3,433 12,825 5,251 3,598 543 3,433 12,825 Generation Exelon As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Pledged assets for Zion Station decommissioning Cash equivalents 9 — — — 9 9 — — — 9 Equities — — — — — — — — — — Middle market lending — — — — — — — — — — Pledged assets for Zion Station decommissioning subtotal 9 — — — 9 9 — — — 9 Rabbi trust investments Cash equivalents 5 — — — 5 48 — — — 48 Mutual funds 24 — — — 24 72 — — — 72 Fixed income — — — — — — 15 — — 15 Life insurance contracts — 22 — — 22 — 70 38 — 108 Rabbi trust investments subtotal (f) 29 22 — — 51 120 85 38 — 243 Commodity derivative assets Economic hedges 541 2,760 1,470 — 4,771 541 2,760 1,470 — 4,771 Proprietary trading — 69 77 — 146 — 69 77 — 146 Effect of netting and allocation of (e) (582 ) (2,357 ) (732 ) — (3,671 ) (582 ) (2,357 ) (732 ) — (3,671 ) Commodity derivative assets subtotal (41 ) 472 815 — 1,246 (41 ) 472 815 — 1,246 Interest rate and foreign currency derivative assets Derivatives designated as hedging instruments — — — — — — — — — — Economic hedges — 13 — — 13 — 13 — — 13 Effect of netting and allocation of collateral — (3 ) — — (3 ) — (3 ) — — (3 ) Interest rate and foreign currency derivative assets subtotal — 10 — — 10 — 10 — — 10 Other investments — — 42 — 42 — — 42 — 42 Total assets 5,829 4,102 1,400 3,433 14,764 6,582 4,165 1,438 3,433 15,618 Generation Exelon As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Liabilities Commodity derivative liabilities Economic hedges (642 ) (2,963 ) (1,027 ) — (4,632 ) (642 ) (2,963 ) (1,276 ) — (4,881 ) Proprietary trading — (73 ) (21 ) — (94 ) — (73 ) (21 ) — (94 ) Effect of netting and allocation of (e) 639 2,581 808 — 4,028 639 2,581 808 — 4,028 Commodity derivative liabilities subtotal (3 ) (455 ) (240 ) — (698 ) (3 ) (455 ) (489 ) — (947 ) Interest rate and foreign currency derivative liabilities Derivatives designated as hedging instruments — — — — — — (4 ) — — (4 ) Economic hedges — (6 ) — — (6 ) — (6 ) — — (6 ) Effect of netting and allocation of collateral — 3 — — 3 — 3 — — 3 Interest rate and foreign currency derivative liabilities subtotal — (3 ) — — (3 ) — (7 ) — — (7 ) Deferred compensation obligation — (35 ) — — (35 ) — (137 ) — — (137 ) Total liabilities (3 ) (493 ) (240 ) — (736 ) (3 ) (599 ) (489 ) — (1,091 ) Total net assets $ 5,826 $ 3,609 $ 1,160 $ 3,433 $ 14,028 $ 6,579 $ 3,566 $ 949 $ 3,433 $ 14,527 Generation Exelon As of December 31, 2017 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Assets Cash equivalents (a) $ 168 $ — $ — $ — $ 168 $ 656 $ — $ — $ — $ 656 NDT fund investments Cash equivalents (b) 135 85 — — 220 135 85 — — 220 Equities 4,163 915 — 2,176 7,254 4,163 915 — 2,176 7,254 Fixed income Corporate debt — 1,614 251 — 1,865 — 1,614 251 — 1,865 U.S. Treasury and agencies 1,917 52 — — 1,969 1,917 52 — — 1,969 Foreign governments — 82 — — 82 — 82 — — 82 State and municipal debt — 263 — — 263 — 263 — — 263 Other (c) — 47 — 510 557 — 47 — 510 557 Fixed income subtotal 1,917 2,058 251 510 4,736 1,917 2,058 251 510 4,736 Generation Exelon As of December 31, 2017 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Middle market lending — — 397 131 528 — — 397 131 528 Private equity — — — 222 222 — — — 222 222 Real estate — — — 471 471 — — — 471 471 NDT fund investments subtotal (d) 6,215 3,058 648 3,510 13,431 6,215 3,058 648 3,510 13,431 Pledged assets for Zion Station decommissioning Cash equivalents 2 — — — 2 2 — — — 2 Equities — 1 — — 1 — 1 — — 1 Middle market lending — — 12 24 36 — — 12 24 36 Pledged assets for Zion Station decommissioning subtotal 2 1 12 24 39 2 1 12 24 39 Rabbi trust investments Cash equivalents 5 — — — 5 77 — — — 77 Mutual funds 23 — — — 23 58 — — — 58 Fixed income — — — — — — 12 — — 12 Life insurance contracts — 22 — — 22 — 71 22 — 93 Rabbi trust investments subtotal (f) 28 22 — — 50 135 83 22 — 240 Commodity derivative assets Economic hedges 557 2,378 1,290 — 4,225 557 2,378 1,290 — 4,225 Proprietary trading 2 31 35 — 68 2 31 35 — 68 Effect of netting and allocation of (e) (585 ) (1,769 ) (635 ) — (2,989 ) (585 ) (1,769 ) (635 ) — (2,989 ) Commodity derivative assets subtotal (26 ) 640 690 — 1,304 (26 ) 640 690 — 1,304 Interest rate and foreign currency derivative assets Derivatives designated as hedging instruments — 3 — — 3 — 6 — — 6 Economic hedges — 10 — — 10 — 10 — — 10 Effect of netting and allocation of collateral (2 ) (5 ) — — (7 ) (2 ) (5 ) — — (7 ) Interest rate and foreign currency derivative assets subtotal (2 ) 8 — — 6 (2 ) 11 — — 9 Other investments — — 37 — 37 — — 37 — 37 Total assets 6,385 3,729 1,387 3,534 15,035 6,980 3,793 1,409 3,534 15,716 Generation Exelon As of December 31, 2017 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Liabilities Commodity derivative liabilities Economic hedges (712 ) (2,226 ) (845 ) — (3,783 ) (713 ) (2,226 ) (1,101 ) — (4,040 ) Proprietary trading (2 ) (42 ) (9 ) — (53 ) (2 ) (42 ) (9 ) — (53 ) Effect of netting and allocation of (e) 650 2,089 716 — 3,455 651 2,089 716 — 3,456 Commodity derivative liabilities subtotal (64 ) (179 ) (138 ) — (381 ) (64 ) (179 ) (394 ) — (637 ) Interest rate and foreign currency derivative liabilities Derivatives designated as hedging instruments — (2 ) — — (2 ) — (2 ) — — (2 ) Economic hedges (1 ) (8 ) — — (9 ) (1 ) (8 ) — — (9 ) Effect of netting and allocation of collateral 2 5 — — 7 2 5 — — 7 Interest rate and foreign currency derivative liabilities subtotal 1 (5 ) — — (4 ) 1 (5 ) — — (4 ) Deferred compensation obligation — (38 ) — — (38 ) — (145 ) — — (145 ) Total liabilities (63 ) (222 ) (138 ) — (423 ) (63 ) (329 ) (394 ) — (786 ) Total net assets $ 6,322 $ 3,507 $ 1,249 $ 3,534 $ 14,612 $ 6,917 $ 3,464 $ 1,015 $ 3,534 $ 14,930 __________ (a) Generation excludes cash of $283 million and $259 million at December 31, 2018 and 2017 and restricted cash of $39 million and $127 million at December 31, 2018 and 2017 . Exelon excludes cash of $458 million and $389 million at December 31, 2018 and 2017 and restricted cash of $80 million and $145 million at December 31, 2018 and 2017 and includes long-term restricted cash of $185 million and $85 million at December 31, 2018 and 2017 , which is reported in Other deferred debits in the Consolidated Balance Sheets. (b) Includes $50 million and $77 million of cash received from outstanding repurchase agreements at December 31, 2018 and 2017 , respectively, and is offset by an obligation to repay upon settlement of the agreement as discussed in (d) below. (c) Includes derivative instruments of $44 million and less than $1 million , which have a total notional amount of $1,432 million and $811 million at December 31, 2018 and 2017 , respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the fiscal years ended and do not represent the amount of the company's exposure to credit or market loss. (d) Excludes net liabilities of $130 million and $82 million at December 31, 2018 and 2017 , respectively. These items consist of receivables related to pending securities sales, interest and dividend receivables, repurchase agreement obligations, and payables related to pending securities purchases. The repurchase agreements are generally short-term in nature with durations generally of 30 days or less. (e) Excludes net assets of less than $1 million at December 31, 2018 and 2017 . These items consist of receivables related to pending securities sales, interest and dividend receivables, and payables related to pending securities purchases. (f) The amount of unrealized gains/(losses) at Generation totaled less than $1 million and $1 million for the years ended December 31, 2018 and 2017 , respectively. The amount of unrealized gains/(losses) at Exelon totaled $1 million for the years ended December 31, 2018 and 2017 , respectively. (g) Collateral posted/(received) from counterparties totaled $57 million , $224 million and $76 million allocated to Level 1, Level 2 and Level 3 mark-to-market derivatives, respectively, as of December 31, 2018 . Collateral posted/(received) from counterparties totaled $65 million , $320 million and $81 million allocated to Level 1, Level 2 and Level 3 mark-to-market derivatives, respectively, as of December 31, 2017 . |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block] | The following tables present assets and liabilities measured and recorded at fair value in Exelon's and Generation’s Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of December 31, 2018 and 2017 : Generation Exelon As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Assets Cash equivalents (a) $ 581 $ — $ — $ — $ 581 $ 1,243 $ — $ — $ — $ 1,243 NDT fund investments Cash equivalents (b) 252 86 — — 338 252 86 — — 338 Equities 2,918 1,591 — 1,381 5,890 2,918 1,591 — 1,381 5,890 Fixed income Corporate debt — 1,593 230 — 1,823 — 1,593 230 — 1,823 U.S. Treasury and agencies 2,081 99 — — 2,180 2,081 99 — — 2,180 Foreign governments — 50 — — 50 — 50 — — 50 State and municipal debt — 149 — — 149 — 149 — — 149 Other (c) — 30 — 846 876 — 30 — 846 876 Fixed income subtotal 2,081 1,921 230 846 5,078 2,081 1,921 230 846 5,078 Middle market lending — — 313 367 680 — — 313 367 680 Private equity — — — 329 329 — — — 329 329 Real estate — — — 510 510 — — — 510 510 NDT fund investments subtotal (d) 5,251 3,598 543 3,433 12,825 5,251 3,598 543 3,433 12,825 Generation Exelon As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Pledged assets for Zion Station decommissioning Cash equivalents 9 — — — 9 9 — — — 9 Equities — — — — — — — — — — Middle market lending — — — — — — — — — — Pledged assets for Zion Station decommissioning subtotal 9 — — — 9 9 — — — 9 Rabbi trust investments Cash equivalents 5 — — — 5 48 — — — 48 Mutual funds 24 — — — 24 72 — — — 72 Fixed income — — — — — — 15 — — 15 Life insurance contracts — 22 — — 22 — 70 38 — 108 Rabbi trust investments subtotal (f) 29 22 — — 51 120 85 38 — 243 Commodity derivative assets Economic hedges 541 2,760 1,470 — 4,771 541 2,760 1,470 — 4,771 Proprietary trading — 69 77 — 146 — 69 77 — 146 Effect of netting and allocation of (e) (582 ) (2,357 ) (732 ) — (3,671 ) (582 ) (2,357 ) (732 ) — (3,671 ) Commodity derivative assets subtotal (41 ) 472 815 — 1,246 (41 ) 472 815 — 1,246 Interest rate and foreign currency derivative assets Derivatives designated as hedging instruments — — — — — — — — — — Economic hedges — 13 — — 13 — 13 — — 13 Effect of netting and allocation of collateral — (3 ) — — (3 ) — (3 ) — — (3 ) Interest rate and foreign currency derivative assets subtotal — 10 — — 10 — 10 — — 10 Other investments — — 42 — 42 — — 42 — 42 Total assets 5,829 4,102 1,400 3,433 14,764 6,582 4,165 1,438 3,433 15,618 Generation Exelon As of December 31, 2018 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Liabilities Commodity derivative liabilities Economic hedges (642 ) (2,963 ) (1,027 ) — (4,632 ) (642 ) (2,963 ) (1,276 ) — (4,881 ) Proprietary trading — (73 ) (21 ) — (94 ) — (73 ) (21 ) — (94 ) Effect of netting and allocation of (e) 639 2,581 808 — 4,028 639 2,581 808 — 4,028 Commodity derivative liabilities subtotal (3 ) (455 ) (240 ) — (698 ) (3 ) (455 ) (489 ) — (947 ) Interest rate and foreign currency derivative liabilities Derivatives designated as hedging instruments — — — — — — (4 ) — — (4 ) Economic hedges — (6 ) — — (6 ) — (6 ) — — (6 ) Effect of netting and allocation of collateral — 3 — — 3 — 3 — — 3 Interest rate and foreign currency derivative liabilities subtotal — (3 ) — — (3 ) — (7 ) — — (7 ) Deferred compensation obligation — (35 ) — — (35 ) — (137 ) — — (137 ) Total liabilities (3 ) (493 ) (240 ) — (736 ) (3 ) (599 ) (489 ) — (1,091 ) Total net assets $ 5,826 $ 3,609 $ 1,160 $ 3,433 $ 14,028 $ 6,579 $ 3,566 $ 949 $ 3,433 $ 14,527 Generation Exelon As of December 31, 2017 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Assets Cash equivalents (a) $ 168 $ — $ — $ — $ 168 $ 656 $ — $ — $ — $ 656 NDT fund investments Cash equivalents (b) 135 85 — — 220 135 85 — — 220 Equities 4,163 915 — 2,176 7,254 4,163 915 — 2,176 7,254 Fixed income Corporate debt — 1,614 251 — 1,865 — 1,614 251 — 1,865 U.S. Treasury and agencies 1,917 52 — — 1,969 1,917 52 — — 1,969 Foreign governments — 82 — — 82 — 82 — — 82 State and municipal debt — 263 — — 263 — 263 — — 263 Other (c) — 47 — 510 557 — 47 — 510 557 Fixed income subtotal 1,917 2,058 251 510 4,736 1,917 2,058 251 510 4,736 Generation Exelon As of December 31, 2017 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Middle market lending — — 397 131 528 — — 397 131 528 Private equity — — — 222 222 — — — 222 222 Real estate — — — 471 471 — — — 471 471 NDT fund investments subtotal (d) 6,215 3,058 648 3,510 13,431 6,215 3,058 648 3,510 13,431 Pledged assets for Zion Station decommissioning Cash equivalents 2 — — — 2 2 — — — 2 Equities — 1 — — 1 — 1 — — 1 Middle market lending — — 12 24 36 — — 12 24 36 Pledged assets for Zion Station decommissioning subtotal 2 1 12 24 39 2 1 12 24 39 Rabbi trust investments Cash equivalents 5 — — — 5 77 — — — 77 Mutual funds 23 — — — 23 58 — — — 58 Fixed income — — — — — — 12 — — 12 Life insurance contracts — 22 — — 22 — 71 22 — 93 Rabbi trust investments subtotal (f) 28 22 — — 50 135 83 22 — 240 Commodity derivative assets Economic hedges 557 2,378 1,290 — 4,225 557 2,378 1,290 — 4,225 Proprietary trading 2 31 35 — 68 2 31 35 — 68 Effect of netting and allocation of (e) (585 ) (1,769 ) (635 ) — (2,989 ) (585 ) (1,769 ) (635 ) — (2,989 ) Commodity derivative assets subtotal (26 ) 640 690 — 1,304 (26 ) 640 690 — 1,304 Interest rate and foreign currency derivative assets Derivatives designated as hedging instruments — 3 — — 3 — 6 — — 6 Economic hedges — 10 — — 10 — 10 — — 10 Effect of netting and allocation of collateral (2 ) (5 ) — — (7 ) (2 ) (5 ) — — (7 ) Interest rate and foreign currency derivative assets subtotal (2 ) 8 — — 6 (2 ) 11 — — 9 Other investments — — 37 — 37 — — 37 — 37 Total assets 6,385 3,729 1,387 3,534 15,035 6,980 3,793 1,409 3,534 15,716 Generation Exelon As of December 31, 2017 Level 1 Level 2 Level 3 Not subject to leveling Total Level 1 Level 2 Level 3 Not subject to leveling Total Liabilities Commodity derivative liabilities Economic hedges (712 ) (2,226 ) (845 ) — (3,783 ) (713 ) (2,226 ) (1,101 ) — (4,040 ) Proprietary trading (2 ) (42 ) (9 ) — (53 ) (2 ) (42 ) (9 ) — (53 ) Effect of netting and allocation of (e) 650 2,089 716 — 3,455 651 2,089 716 — 3,456 Commodity derivative liabilities subtotal (64 ) (179 ) (138 ) — (381 ) (64 ) (179 ) (394 ) — (637 ) Interest rate and foreign currency derivative liabilities Derivatives designated as hedging instruments — (2 ) — — (2 ) — (2 ) — — (2 ) Economic hedges (1 ) (8 ) — — (9 ) (1 ) (8 ) — — (9 ) Effect of netting and allocation of collateral 2 5 — — 7 2 5 — — 7 Interest rate and foreign currency derivative liabilities subtotal 1 (5 ) — — (4 ) 1 (5 ) — — (4 ) Deferred compensation obligation — (38 ) — — (38 ) — (145 ) — — (145 ) Total liabilities (63 ) (222 ) (138 ) — (423 ) (63 ) (329 ) (394 ) — (786 ) Total net assets $ 6,322 $ 3,507 $ 1,249 $ 3,534 $ 14,612 $ 6,917 $ 3,464 $ 1,015 $ 3,534 $ 14,930 __________ (a) Generation excludes cash of $283 million and $259 million at December 31, 2018 and 2017 and restricted cash of $39 million and $127 million at December 31, 2018 and 2017 . Exelon excludes cash of $458 million and $389 million at December 31, 2018 and 2017 and restricted cash of $80 million and $145 million at December 31, 2018 and 2017 and includes long-term restricted cash of $185 million and $85 million at December 31, 2018 and 2017 , which is reported in Other deferred debits in the Consolidated Balance Sheets. (b) Includes $50 million and $77 million of cash received from outstanding repurchase agreements at December 31, 2018 and 2017 , respectively, and is offset by an obligation to repay upon settlement of the agreement as discussed in (d) below. (c) Includes derivative instruments of $44 million and less than $1 million , which have a total notional amount of $1,432 million and $811 million at December 31, 2018 and 2017 , respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the fiscal years ended and do not represent the amount of the company's exposure to credit or market loss. (d) Excludes net liabilities of $130 million and $82 million at December 31, 2018 and 2017 , respectively. These items consist of receivables related to pending securities sales, interest and dividend receivables, repurchase agreement obligations, and payables related to pending securities purchases. The repurchase agreements are generally short-term in nature with durations generally of 30 days or less. (e) Excludes net assets of less than $1 million at December 31, 2018 and 2017 . These items consist of receivables related to pending securities sales, interest and dividend receivables, and payables related to pending securities purchases. (f) The amount of unrealized gains/(losses) at Generation totaled less than $1 million and $1 million for the years ended December 31, 2018 and 2017 , respectively. The amount of unrealized gains/(losses) at Exelon totaled $1 million for the years ended December 31, 2018 and 2017 , respectively. (g) Collateral posted/(received) from counterparties totaled $57 million , $224 million and $76 million allocated to Level 1, Level 2 and Level 3 mark-to-market derivatives, respectively, as of December 31, 2018 . Collateral posted/(received) from counterparties totaled $65 million , $320 million and $81 million allocated to Level 1, Level 2 and Level 3 mark-to-market derivatives, respectively, as of December 31, 2017 . |
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Text Block] | The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis during the years ended December 31, 2018 and 2017 : Generation ComEd PHI Exelon For the year ended December 31, 2018 NDT Fund Investments Pledged Assets Mark-to-Market Other Total Generation Mark-to-Market Derivatives Life Insurance Contracts (c) Eliminated in Consolidation Total Balance as of January 1, 2018 $ 648 $ 12 $ 552 $ 37 $ 1,249 $ (256 ) $ 22 $ — $ 1,015 Total realized / unrealized gains (losses) Included in net income — — (105 ) (a) 3 (102 ) — 4 — (98 ) Included in noncurrent payables to affiliates (1 ) — — — (1 ) — — 1 — Included in payable for Zion Station decommissioning — 7 — — 7 — — — 7 Included in regulatory assets/liabilities — — — — — 7 (b) — (1 ) 6 Change in collateral — — (5 ) — (5 ) — — — (5 ) Purchases, sales, issuances and settlements Purchases 36 1 190 (e) 4 231 — — — 231 Sales — (20 ) (4 ) — (24 ) — — — (24 ) Issuances — — — — — — — — — Settlements (140 ) — 5 — (135 ) — 12 — (123 ) Transfers into Level 3 — — (22 ) (d) — (22 ) — — — (22 ) Transfers out of Level 3 — — (36 ) (d) (2 ) (38 ) — — — (38 ) Other miscellaneous — — — — — — — — Balance as of December 31, 2018 $ 543 $ — $ 575 $ 42 $ 1,160 $ (249 ) $ 38 $ — $ 949 The amount of total (losses) gains included in income attributed to the change in unrealized (losses) gains related to assets and liabilities held as of December 31, 2018 $ (5 ) $ — $ 165 $ 3 $ 163 $ — $ — $ — $ 163 Generation ComEd PHI Exelon For the year ended December 31, 2017 NDT Fund Investments Pledged Assets for Zion Station Decommissioning Mark-to-Market Derivatives Other Investments Total Generation Mark-to-Market Derivatives Life Insurance Contracts (c) Eliminated in Consolidation Total Balance as of January 1, 2017 $ 677 $ 19 $ 493 $ 42 $ 1,231 $ (258 ) $ 20 $ — $ 993 Total realized / unrealized gains (losses) Included in net income 3 — (90 ) (a) 3 (84 ) — 3 — (81 ) Included in noncurrent payables to affiliates 6 — — — 6 — — (6 ) — Included in payable for Zion Station decommissioning — (8 ) — — (8 ) — — (8 ) Included in regulatory assets/liabilities — — — — — 2 (b) — 6 8 Change in collateral — — 20 — 20 — — — 20 Purchases, sales, issuances and settlements Purchases 64 1 178 5 248 — — — 248 Sales — — (16 ) — (16 ) — — — (16 ) Issuances — — — — — — (1 ) — (1 ) Settlements (102 ) — (8 ) — (110 ) — — — (110 ) Transfers into Level 3 — — (6 ) (d) — (6 ) — — — (6 ) Transfers out of Level 3 — — (50 ) (d) (11 ) (61 ) — — — (61 ) Other miscellaneous $ — $ — $ 31 $ (2 ) $ 29 $ — $ — $ — $ 29 Balance as of December 31, 2017 $ 648 $ 12 $ 552 $ 37 $ 1,249 $ (256 ) $ 22 $ — $ 1,015 The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities held as of December 31, 2017 $ 1 $ — $ 254 $ 3 $ 258 $ — $ 3 $ — $ 261 __________ (a) Includes a reduction for the reclassification of $265 million and $352 million of realized gains due to the settlement of derivative contracts for the years ended December 31, 2018 and 2017 , respectively. (b) Includes $24 million of decreases in fair value and an increase for realized losses due to settlements of $17 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2018 . Includes $18 million of decreases in fair value and an increase for realized losses due to settlements of $20 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2017 . (c) The amounts represented are life insurance contracts at Pepco. (d) Transfers into and out of Level 3 generally occur when the contract tenor becomes less and more observable respectively, primarily due to changes in market liquidity or assumptions for certain commodity contracts. (e) Includes $(19) million of fair value from contracts acquired as a result of the Everett Marine Terminal acquisition |
Total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis | following tables present the income statement classification of the total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis during the years ended December 31, 2018 and 2017 : Generation PHI Exelon Operating Revenues Purchased Power and Fuel Other, net Operating and Operating Revenues Purchased Power and Fuel Operating and Other, net Total (losses) gains included in net income for the year ended December 31, 2018 $ (7 ) $ (93 ) $ 3 $ 4 $ (7 ) $ (93 ) $ 4 $ 3 Change in the unrealized gains relating to assets and liabilities held for the year ended December 31, 2018 144 21 (2 ) — 144 21 — (2 ) Generation PHI Exelon Operating Revenues Purchased Power and Fuel Other, net Operating and Operating Revenues Purchased Power and Fuel Operating and Other, net Total gains (losses) included in net income for the year ended December 31, 2017 $ 28 $ (126 ) $ 6 $ 3 $ 28 $ (126 ) $ 3 $ 6 Change in the unrealized gains (losses) relating to assets and liabilities held for the year ended December 31, 2017 290 (36 ) 4 3 290 (36 ) 3 4 Val |
Derivative Financial Instrume_2
Derivative Financial Instruments (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Summary of the derivative fair value | December 31, 2018 : Generation Exelon Corporate Exelon Description Economic Hedges Collateral and Netting (a) Subtotal Economic Total Mark-to-market derivative assets (current assets) $ 5 $ (2 ) $ 3 $ — $ 3 Mark-to-market derivative assets (noncurrent assets) 8 (1 ) 7 — 7 Total mark-to-market derivative assets 13 (3 ) 10 — 10 Mark-to-market derivative liabilities (current liabilities) (4 ) 2 (2 ) — (2 ) Mark-to-market derivative liabilities (noncurrent liabilities) (2 ) 1 (1 ) (4 ) (5 ) Total mark-to-market derivative liabilities (6 ) 3 (3 ) (4 ) (7 ) Total mark-to-market derivative net assets (liabilities) $ 7 $ — $ 7 $ (4 ) $ 3 __________ (a) Exelon and Generation net all available amounts allowed under the derivative authoritative guidance on the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases, Exelon and Generation may have other offsetting counterparty exposures subject to a master netting or similar agreement, such as accrued interest, transactions that do not qualify as derivatives, letters of credit and other forms of non-cash collateral, which are not reflected in the table above. The following table provides a summary of the interest rate and foreign exchange hedge balances recorded by the Registrants as of December 31, 2017 : Generation Exelon Corporate Exelon Description Derivatives Designated as Hedging Instruments Economic Hedges Collateral and Netting (a) Subtotal Derivatives Total Mark-to-market derivative assets (current assets) $ — $ 10 $ (7 ) $ 3 $ — $ 3 Mark-to-market derivative assets (noncurrent assets) 3 — — 3 3 6 Total mark-to-market derivative assets 3 10 (7 ) 6 3 9 Mark-to-market derivative liabilities (current liabilities) (2 ) (7 ) 7 (2 ) — (2 ) Mark-to-market derivative liabilities (noncurrent liabilities) — (2 ) — (2 ) — (2 ) Total mark-to-market derivative liabilities (2 ) (9 ) 7 (4 ) — (4 ) Total mark-to-market derivative net assets (liabilities) $ 1 $ 1 $ — $ 2 $ 3 $ 5 __________ (a) Exelon and Generation net all available amounts allowed under the derivative authoritative guidance on the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases, Exelon and Generation may have other offsetting counterparty exposures subject to a master netting or similar agreement, such as accrued interest, transactions that do not qualify as derivatives, letters of credit and other forms of non-cash collateral, which are not reflected in the table above. The following table provides a summary of the derivative fair value balances related to commodity contracts recorded by the Registrants as of December 31, 2018 : Generation ComEd Exelon Description Economic Hedges Proprietary Trading Collateral and Netting (a)(d) Subtotal (b) Economic Hedges (c) Total Derivatives Mark-to-market derivative assets (current assets) $ 3,505 $ 105 $ (2,809 ) $ 801 $ — $ 801 Mark-to-market derivative assets (noncurrent assets) 1,266 41 (862 ) 445 — 445 Total mark-to-market derivative assets 4,771 146 (3,671 ) 1,246 — 1,246 Mark-to-market derivative liabilities (current liabilities) (3,429 ) (74 ) 3,056 (447 ) (26 ) (473 ) Mark-to-market derivative liabilities (noncurrent liabilities) (1,203 ) (20 ) 972 (251 ) (223 ) (474 ) Total mark-to-market derivative liabilities (4,632 ) (94 ) 4,028 (698 ) (249 ) (947 ) Total mark-to-market derivative net assets (liabilities) $ 139 $ 52 $ 357 $ 548 $ (249 ) $ 299 __________ (a) Exelon and Generation net all available amounts allowed under the derivative authoritative guidance on the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases, Exelon and Generation may have other offsetting exposures, subject to a master netting or similar agreement, such as trade receivables and payables, transactions that do not qualify as derivatives, letters of credit and other forms of non-cash collateral. These are not reflected in the table above. (b) Current and noncurrent assets are shown net of collateral of $121 million and $51 million , respectively, and current and noncurrent liabilities are shown net of collateral of $125 million and $60 million , respectively. The total cash collateral posted, net of cash collateral received and offset against mark-to-market assets and liabilities was $357 million at December 31, 2018 . (c) Includes current and noncurrent liabilities relating to floating-to-fixed energy swap contracts with unaffiliated suppliers. (d) Of the collateral posted/(received), $(94) million represents variation margin on the exchanges. The following table provides a summary of the derivative fair value balances related to commodity contracts recorded by the Registrants as of December 31, 2017 : Generation ComEd Exelon Description Economic Hedges Proprietary Trading Collateral and Netting (a)(d) Subtotal (b) Economic Hedges (c) Total Derivatives Mark-to-market derivative assets (current assets) $ 3,061 $ 56 $ (2,144 ) $ 973 $ — $ 973 Mark-to-market derivative assets (noncurrent assets) 1,164 12 (845 ) 331 — 331 Total mark-to-market derivative assets 4,225 68 (2,989 ) 1,304 — 1,304 Mark-to-market derivative liabilities (current liabilities) (2,646 ) (43 ) 2,480 (209 ) (21 ) (230 ) Mark-to-market derivative liabilities (noncurrent liabilities) (1,137 ) (10 ) 975 (172 ) (235 ) (407 ) Total mark-to-market derivative liabilities (3,783 ) (53 ) 3,455 (381 ) (256 ) (637 ) Total mark-to-market derivative net assets (liabilities) $ 442 $ 15 $ 466 $ 923 $ (256 ) $ 667 __________ (a) Exelon and Generation net all available amounts allowed under the derivative authoritative guidance on the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases, Exelon and Generation may have other offsetting exposures, subject to a master netting or similar agreement, such as trade receivables and payables, transactions that do not qualify as derivatives, and letters of credit and other forms of non-cash collateral. These are not reflected in the table above. (b) Current and noncurrent assets are shown net of collateral of $169 million and $53 million , respectively, and current and noncurrent liabilities are shown net of collateral of $167 million and $77 million , respectively. The total cash collateral posted, net of cash collateral received and offset against mark-to-market assets and liabilities was $466 million at December 31, 2017 . (c) Includes current and noncurrent liabilities relating to floating-to-fixed energy swap contracts with unaffiliated suppliers. (d) Of the collateral posted/(received), $(117) million represents variation margin on the exchanges |
Derivative Instruments, Gain (Loss) | For the years ended December 31, 2018 , 2017 and 2016 , Exelon and Generation recognized the following net pre-tax mark-to-market gains (losses) in the Consolidated Statements of Operations and Comprehensive Income and are included in “Net fair value changes related to derivatives” in Exelon’s and Generation’s Consolidated Statements of Cash Flows. For the Years Ended December 31, 2018 2017 2016 Income Statement Location Gain (Loss) Generation Operating Revenues $ 7 $ (6 ) $ (10 ) Generation Purchased Power and Fuel (9 ) — — Generation Interest Expense (7 ) (3 ) — Total Generation $ (9 ) $ (9 ) $ (10 ) For the Years Ended December 31, 2018 2017 2016 Income Statement Location Gain (Loss) Exelon Operating Revenues $ 7 $ (6 ) $ (10 ) Exelon Purchased Power and Fuel (9 ) — — Exelon Interest Expense (4 ) (3 ) — Total Exelon $ (6 ) $ (9 ) $ (10 ) Exelon and Generation include the gain or loss on the hedged items and the offsetting loss or gain on the related interest rate swaps as follows: Year Ended December 31, Income Statement Location 2018 2017 2016 2018 2017 2016 Loss on Swaps Gain on Borrowings Exelon Interest expense $ (11 ) $ (13 ) $ (9 ) $ 20 $ 28 $ 23 For the years ended December 31, 2018 , 2017 and 2016 , Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses) which are also located in the "Net fair value changes related to derivatives" in the Consolidated Statements of Cash Flows. For the Years Ended December 31, 2018 2017 2016 Income Statement Location Gain (Loss) Operating revenues $ (270 ) $ (126 ) $ (490 ) Purchased power and fuel (47 ) (43 ) 459 Total Exelon and Generation $ (317 ) $ (169 ) $ (31 ) |
The activity of accumulated OCI related to cash flow hedges | Total Cash Flow Hedge AOCI Activity, Net of Income Tax Generation Exelon For the Year Ended December 31, 2018 Income Statement Location Total Cash Total Cash Flow Hedges AOCI derivative loss at December 31, 2017 $ (16 ) $ (14 ) Effective portion of changes in fair value 11 11 Reclassifications from AOCI to net income Interest expense 1 1 AOCI derivative loss at December 31, 2018 $ (4 ) $ (2 ) Total Cash Flow Hedge AOCI Activity, Net of Income Tax Generation Exelon For the Year Ended December 31, 2017 Income Statement Location Total Cash Total Cash Flow Hedges AOCI derivative loss at December 31, 2016 $ (19 ) $ (17 ) Effective portion of changes in fair value (1 ) (1 ) Reclassifications from AOCI to net income Interest expense 4 (a) 4 (a) AOCI derivative loss at December 31, 2017 $ (16 ) $ (14 ) __________ (a) Amount is net of related income tax expense of $1 million for the year ended December 31, 2017 . |
Change in fair value of derivative contracts | For the years ended December 31, 2018 , 2017 and 2016 , Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses). For the Years Ended December 31, 2018 2017 2016 Income Statement Location Loss Operating revenues $ — $ (1 ) $ (1 ) For the years ended December 31, 2018 , 2017 and 2016 , Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses) which are also included in the "Net fair value changes related to derivatives" in the Consolidated Statements of Cash Flows. The Utility Registrants do not execute derivatives for proprietary trading purposes. For the Years Ended December 31, 2018 2017 2016 Income Statement Location Gain Operating revenues $ 17 $ 6 $ 2 |
Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block] | The following table provides notional amounts outstanding held by Exelon and Generation at December 31, 2018 related to interest rate swaps and foreign currency exchange rate swaps. Generation Exelon Corporate Exelon Foreign currency exchange rate swaps $ 268 $ — $ 268 Interest rate swaps 620 800 1,420 Total $ 888 $ 800 $ 1,688 The following table provides notional amounts outstanding held by Exelon and Generation at December 31, 2017 related to interest rate swaps and foreign currency exchange rate swaps. Generation Exelon Corporate Exelon Foreign currency exchange rate swaps $ 94 $ — $ 94 Interest rate swaps (a) 1 — 1 Total $ 95 $ — $ 95 __________ (a) On July 1, 2018, Exelon and Generation de-designated its fair value and cash flow hedges. The table excludes amounts of $800 million of fixed-to-floating hedges that were previously designated as fair value hedges by Exelon and $636 million of floating-to-fixed hedges that were previously designated as cash flow hedges by Exelon and Generation as of December 31, 2017. |
Disclosure of Credit Derivatives [Table Text Block] | The figures in the tables below exclude credit risk exposure from individual retail counterparties, nuclear fuel procurement contracts and exposure through RTOs, ISOs, NYMEX, ICE, NASDAQ, NGX and Nodal commodity exchanges. Additionally, the figures in the tables below exclude exposures with affiliates, including net receivables with ComEd, PECO, BGE, Pepco, DPL and ACE of $43 million , $30 million , $24 million , $28 million , $7 million and $5 million as of December 31, 2018 , respectively. Rating as of December 31, 2018 Total Exposure Before Credit Collateral Credit Collateral (a) Net Exposure Number of Counterparties Greater than 10% of Net Exposure Net Exposure of Counterparties Greater than 10% of Net Exposure Investment grade $ 795 $ — $ 795 1 $ 153 Non-investment grade 133 45 88 — — No external ratings Internally rated — investment grade 181 1 180 — — Internally rated — non-investment grade 92 6 86 — — Total $ 1,201 $ 52 $ 1,149 1 $ 153 Net Credit Exposure by Type of Counterparty December 31, 2018 Financial institutions $ 12 Investor-owned utilities, marketers, power producers 737 Energy cooperatives and municipalities 324 Other 76 Total $ 1,149 __________ (a) As of December 31, 2018 , credit collateral held from counterparties where Generation had credit exposure included $17 million of cash and $35 million of letters of credit. The credit collateral does not include non-liquid collateral. |
Fair Value, Concentration of Risk [Table Text Block] | For the Years Ended December 31, Credit-Risk Related Contingent Feature 2018 2017 Gross fair value of derivative contracts containing this feature (a) $ (1,723 ) $ (926 ) Offsetting fair value of in-the-money contracts under master netting arrangements (b) 1,105 577 Net fair value of derivative contracts containing this feature (c) $ (618 ) $ (349 ) __________ (a) Amount represents the gross fair value of out-of-the-money derivative contracts containing credit-risk-related contingent features ignoring the effects of master netting agreements. (b) Amount represents the offsetting fair value of in-the-money derivative contracts under legally enforceable master netting agreements with the same counterparty, which reduces the amount of any liability for which a Registrant could potentially be required to post collateral. (c) Amount represents the net fair value of out-of-the-money derivative contracts containing credit-risk related contingent features after considering the mitigating effects of offsetting positions under master netting arrangements and reflects the actual net liability upon which any potential contingent collateral obligations would be based. |
Debt and Credit Agreements (Tab
Debt and Credit Agreements (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Debt Disclosure [Abstract] | |
Schedule of Short-term Debt | The following table reflects the Registrants' commercial paper programs supported by the revolving credit agreements and bilateral credit agreements at December 31, 2018 and 2017 : Maximum Program Size at December 31, Outstanding Commercial Paper at December 31, Average Interest Rate on Commercial Paper Borrowings for the Year Ended December 31, Commercial Paper Issuer 2018 (a)(b)(c) 2017 (a)(b)(c) 2018 2017 2018 2017 Exelon Corporate $ 600 $ 600 $ — $ — 1.93 % 1.16 % Generation 5,300 5,300 — — 1.96 % 1.23 % ComEd 1,000 1,000 — — 2.14 % 1.24 % PECO 600 600 — — 2.24 % 1.13 % BGE 600 600 35 77 2.18 % 1.28 % Pepco 300 500 40 26 2.24 % 1.06 % DPL 300 500 — 216 2.07 % 1.48 % ACE 300 350 14 108 2.21 % 1.43 % Total $ 9,000 $ 9,450 $ 89 $ 427 __________ (a) Excludes $545 million and $480 million in bilateral credit facilities at December 31, 2018 and 2017 , respectively, and $159 million and $179 million in credit facilities for project finance at December 31, 2018 and 2017 , respectively. These credit facilities do not back Generation's commercial paper program. (b) At December 31, 2018, excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million , $33 million , $34 million , $5 million , $5 million , $5 million and $5 million , respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. At December 31, 2017, excludes $128 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million , $34 million , $34 million , $5 million , $2 million , $2 million , and $2 million , respectively. (c) Pepco, DPL and ACE's revolving credit facility is subject to available borrowing capacity. The borrowing capacity may be increased or decreased during the term of the facility, except that (i) the sum of the borrowing capacity must equal the total amount of the facility, and (ii) the aggregate amount of credit used at any given time by each of Pepco, DPL or ACE may not exceed $900 million or the maximum amount of short-term debt the company is permitted to have outstanding by its regulatory authorities. The total number of the borrowing reallocations may not exceed eight per year during the term of the facility. The following tables present the short-term borrowings activity for Exelon, Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE during 2018 , 2017 and 2016 . Exelon 2018 2017 2016 Average borrowings $ 531 $ 823 $ 1,125 Maximum borrowings outstanding 1,237 2,147 3,076 Average interest rates, computed on a daily basis 2.21 % 1.32 % 0.88 % Average interest rates, at December 31 2.15 % 1.24 % 1.12 % Generation 2018 2017 2016 Average borrowings $ 37 $ 405 $ 536 Maximum borrowings outstanding 583 1,455 1,735 Average interest rates, computed on a daily basis 1.96 % 1.23 % 0.94 % Average interest rates, at December 31 1.96 % 1.23 % 1.14 % ComEd 2018 2017 2016 Average borrowings $ 154 $ 200 $ 256 Maximum borrowings outstanding 520 470 755 Average interest rates, computed on a daily basis 2.14 % 1.24 % 0.77 % Average interest rates, at December 31 2.14 % 1.24 % N/A PECO 2018 2017 2016 Average borrowings $ 68 $ 2 $ — Maximum borrowings outstanding 350 60 — Average interest rates, computed on a daily basis 2.24 % 1.13 % N/A Average interest rates, at December 31 2.24 % 1.13 % N/A BGE 2018 2017 2016 Average borrowings $ 65 $ 54 $ 143 Maximum borrowings outstanding 239 165 369 Average interest rates, computed on a daily basis 2.18 % 1.28 % 0.77 % Average interest rates, computed at December 31 2.18 % 1.28 % 0.95 % PHI Corporate 2018 2017 2016 Average borrowings N/A N/A $ 153 Maximum borrowings outstanding N/A N/A 559 Average interest rates, computed on a daily basis N/A N/A 1.03 % Average interest rates, computed at December 31 N/A N/A N/A Pepco 2018 2017 2016 Average borrowings $ 22 $ 51 $ 4 Maximum borrowings outstanding 90 197 73 Average interest rates, computed on a daily basis 2.24 % 1.06 % 0.71 % Average interest rates, computed at December 31 2.24 % 1.06 % 0.90 % DPL 2018 2017 2016 Average borrowings $ 87 $ 40 $ 33 Maximum borrowings outstanding 245 216 116 Average interest rates, computed on a daily basis 2.07 % 1.48 % 0.68 % Average interest rates, computed at December 31 2.07 % 1.48 % N/A ACE 2018 2017 2016 Average borrowings $ 95 $ 30 $ — Maximum borrowings outstanding 210 133 5 Average interest rates, computed on a daily basis 2.21 % 1.43 % 0.65 % Average interest rates, computed at December 31 2.21 % 1.43 % N/A |
Schedule of Line of Credit Facilities | At December 31, 2018 , the Registrants had the following aggregate bank commitments, credit facility borrowings and available capacity under their respective credit facilities: Available Capacity at December 31, 2018 Borrower Facility Type Aggregate Bank (a) Facility Draws Outstanding Letters of Credit Actual To Support Additional Commercial (b) Exelon Corporate Syndicated Revolver $ 600 $ — $ 9 $ 591 $ 591 Generation Syndicated Revolver 5,300 — 1,203 4,097 4,097 Generation Bilaterals 545 — 353 192 — Generation Project Finance 159 — 119 40 — ComEd Syndicated Revolver 1,000 — 2 998 998 PECO Syndicated Revolver 600 — — 600 600 BGE Syndicated Revolver 600 — 1 599 564 Pepco Syndicated Revolver 300 — 8 292 252 DPL Syndicated Revolver 300 — 1 299 299 ACE Syndicated Revolver 300 — — 300 286 Total $ 9,704 $ — $ 1,696 $ 8,008 $ 7,687 __________ (a) Excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million , $33 million , $34 million , $5 million , $5 million , $5 million and $5 million , respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. As of December 31, 2018 , letters of credit issued under these facilities totaled $5 million and $2 million for Generation and BGE, respectively. |
Schedule Of Credit Agreement Covenants | The following table summarizes the minimum thresholds reflected in the credit agreements for the year ended December 31, 2018 : Exelon Generation ComEd PECO BGE Pepco DPL ACE Credit agreement threshold 2.50 to 1 3.00 to 1 2.00 to 1 2.00 to 1 2.00 to 1 2.00 to 1 2.00 to 1 2.00 to 1 At December 31, 2018 , the interest coverage ratios at the Registrants were as follows: Exelon Generation ComEd PECO BGE Pepco DPL ACE Interest coverage ratio 7.34 10.99 7.34 8.14 9.77 5.98 7.03 5.06 |
Schedule of Long-term Debt Instruments | Maturity Date December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 1.70 % - 5.95 % 2021 - 2048 $ 3,075 $ 2,925 Loan Agreement 2.00 % 2023 50 0 Total long-term debt 3,125 2,925 Unamortized debt discount and premium, net (18 ) (5 ) Unamortized debt issuance costs (23 ) (17 ) Long-term debt due within one year — (500 ) Long-term debt $ 3,084 $ 2,403 Long-term debt to financing trusts (b) Subordinated debentures to PECO Trust III 7.38 % - 7.50 % 2028 $ 81 $ 81 Subordinated debentures to PECO Trust IV 5.75 % 2033 103 103 Long-term debt to financing trusts $ 184 $ 184 __________ (a) Substantially all of PECO’s assets are subject to the lien of its mortgage indenture. (b) Amounts owed to this financing trust are recorded as Long-term debt to financing trusts within PECO’s Consolidated Balance Sheets. BGE Maturity December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 3.38 % - 6.80 % 2021 - 2036 $ 1,137 $ 1,037 Transition bonds (b) 5.55 % 2023 59 90 Total long-term debt 1,196 1,127 Unamortized debt discount and premium, net (1 ) (1 ) Unamortized debt issuance costs (7 ) (5 ) Long-term debt due within one year (18 ) (281 ) Long-term debt $ 1,170 $ 840 __________ (a) Substantially all of ACE's assets are subject to the lien of its respective mortgage indenture. (b) Maturities of ACE's Transition Bonds outstanding at December 31, 2018 are $18 million in 2019, $20 million in 2020 and $21 million in 2021. Lo Maturity December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 1.81 % - 7.90 % 2021 - 2048 $ 5,242 $ 4,743 Senior unsecured notes 7.45 % 2032 185 185 Unsecured Tax-Exempt Bonds 1.74 % - 5.40 % 2024 - 2031 112 112 Medium-terms notes (unsecured) 7.61 % - 7.72 % 2019 - 2027 22 26 Transition bonds (b) 5.55 % 2023 59 90 Notes payable and other (c) 7.28 % - 8.88 % 2019 - 2022 16 33 Total long-term debt 5,636 5,189 Unamortized debt discount and premium, net 4 5 Unamortized debt issuance costs (14 ) (6 ) Fair value adjustment 633 686 Long-term debt due within one year (125 ) (396 ) Long-term debt $ 6,134 $ 5,478 __________ (a) Substantially all of Pepco's, DPL's, and ACE's assets are subject to the lien of its respective mortgage indenture. (b) Transition bonds are recorded as part of Long-term debt within ACE's Consolidated Balance Sheets. (c) Includes Pepco's capital lease obligations of $14 million and $27 million at December 31, 2018 and 2017 , respectively. The following tables present the outstanding long-term debt at the Registrants as of December 31, 2018 and 2017 : Exelon Maturity Date December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 1.70 % - 7.90 % 2019 - 2048 16,496 15,197 Senior unsecured notes 2.45 % - 7.60 % 2019 - 2046 11,285 11,285 Unsecured notes 2.40 % - 6.35 % 2021 - 2048 2,900 2,600 Pollution control notes 2.50 % - 2.70 % 2025 - 2036 435 435 Nuclear fuel procurement contracts 3.15 % 2020 39 82 Notes payable and other (b)(c) 2.85 % - 8.88 % 2019 - 2053 188 405 Junior subordinated notes 3.50 % 2022 1,150 1,150 Long-term software licensing agreement 3.95 % 2024 73 79 Unsecured Tax-Exempt Bonds 1.74 % - 5.40 % — 2024 - 2031 112 112 Medium-Terms Notes (unsecured) 7.61 % - 7.72 % 2019 - 2027 22 26 Transition bonds 5.55 % 2023 59 90 Loan Agreement 2.00 % 2023 50 — Nonrecourse debt: Fixed rates 2.29 % - 6.00 % 2031 - 2037 1,253 1,331 Variable rates (f) 5.81 % 2019 - 2024 849 865 Total long-term debt 34,911 33,657 Unamortized debt discount and premium, net (66 ) (57 ) Unamortized debt issuance costs (216 ) (201 ) Fair value adjustment 795 865 Long-term debt due within one year (e) (1,349 ) (2,088 ) Long-term debt $ 34,075 $ 32,176 Long-term debt to financing trusts (d) Subordinated debentures to ComEd Financing III 6.35 % 2033 $ 206 $ 206 Subordinated debentures to PECO Trust III 7.38 % - 7.50 % 2028 81 81 Subordinated debentures to PECO Trust IV 5.75 % 2033 103 103 Total long-term debt to financing trusts 390 390 Unamortized debt issuance costs — (1 ) Long-term debt to financing trusts $ 390 $ 389 __________ (a) Substantially all of ComEd’s assets other than expressly excepted property and substantially all of PECO’s, Pepco's, DPL's and ACE's assets are subject to the liens of their respective mortgage indentures. (b) Includes capital lease obligations of $36 million and $53 million at December 31, 2018 and 2017 , respectively. Lease payments of $21 million , $5 million , $1 million , $1 million , less than $1 million, and $8 million will be made in 2019 , 2020 , 2021 , 2022 , 2023 , and thereafter, respectively. (c) Includes financing related to Albany Green Energy, LLC (AGE). During the third quarter of 2017, Generation retired $228 million of its outstanding debt balance. (d) Amounts owed to these financing trusts are recorded as Long-term debt to financing trusts within Exelon’s Consolidated Balance Sheets. (e) In January 2019, $300 million of ComEd long-term debt due within one year was paid in full. (f) Excludes interest on CEU Upstream nonrecourse debt, see discussion below. Maturity Date December 31, Rates 2018 2017 Long-term debt Unsecured notes 2.40 % - 6.35 % 2021 - 2048 2,900 2,600 Total long-term debt 2,900 2,600 Unamortized debt discount and premium, net (6 ) (6 ) Unamortized debt issuance costs (18 ) (17 ) Long-term debt $ 2,876 $ 2,577 PHI d Maturity Date December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 2.15 % - 6.45 % 2019 - 2048 $ 8,179 $ 7,529 Notes payable and other (b) 7.49 % 2053 8 147 Total long-term debt 8,187 7,676 Unamortized debt discount and premium, net (23 ) (23 ) Unamortized debt issuance costs (63 ) (52 ) Long-term debt due within one year (d) (300 ) (840 ) Long-term debt $ 7,801 $ 6,761 Long-term debt to financing trust (c) Subordinated debentures to ComEd Financing III 6.35 % 2033 $ 206 $ 206 Total long-term debt to financing trusts 206 206 Unamortized debt issuance costs (1 ) (1 ) Long-term debt to financing trusts $ 205 $ 205 __________ (a) Substantially all of ComEd’s assets, other than expressly excepted property, are subject to the lien of its mortgage indenture. (b) Includes ComEd’s capital lease obligations of $8 million at both December 31, 2018 and 2017 , respectively. Lease payments of less than $1 million annually will be made from 2019 through expiration at 2053. (c) Amount owed to this financing trust is recorded as Long-term debt to financing trust within ComEd’s Consolidated Balance Sheets. (d) ration Maturity Date December 31, Rates 2018 2017 Long-term debt Senior unsecured notes 2.95 % - 7.60 % 2019 - 2042 $ 6,019 $ 6,019 Pollution control notes 2.50 % - 2.70 % 2025 - 2036 435 435 Nuclear fuel procurement contracts 3.15 % 2020 39 82 Notes payable and other (a)(b) 2.85 % - 7.83 % 2019 - 2024 164 223 Nonrecourse debt: Fixed rates 2.29 % - 6.00 % 2031 - 2037 1,253 1,331 Variable rates (c) 5.81 % 2019 - 2024 849 865 Total long-term debt 8,759 8,955 Unamortized debt discount and premium, net (6 ) (8 ) Unamortized debt issuance costs (51 ) (60 ) Fair value adjustment 91 103 Long-term debt due within one year (906 ) (346 ) Long-term debt $ 7,887 $ 8,644 __________ (a) Includes Generation’s capital lease obligations of $14 million and $18 million at December 31, 2018 and 2017 , respectively. Generation will make lease payments of $7 million , $5 million , $1 million , and $1 million in 2019 , 2020 , 2021 , and 2022 , respectively. Lease payments of less than $1 million annually will be made from 2023 through expiration of the final capital lease in 2024. Maturity December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 1.81 % - 4.27 % 2023 - 2048 $ 1,370 $ 1,171 Unsecured Tax-Exempt Bonds 1.74 % - 5.40 % 2024 - 2031 112 112 Medium-terms notes (unsecured) 7.61 % - 7.72 % 2019 - 2027 22 26 Total long-term debt 1,504 1,309 Unamortized debt discount and premium, net 2 2 Unamortized debt issuance costs (12 ) (11 ) Long-term debt due within one year (91 ) (83 ) Long-term debt $ 1,403 $ 1,217 ___ o Maturity December 31, Rates 2018 2017 Long-term debt First mortgage bonds (a) 3.05 % - 7.90 % 2022 - 2048 $ 2,735 $ 2,535 Notes payable and other (b) 7.28 % - 8.88 % 2019 - 2022 16 35 Total long-term debt 2,751 2,570 Unamortized debt discount and premium, net 2 2 Unamortized debt issuance costs (34 ) (32 ) Long-term debt due within one year (15 ) (19 ) Long-term debt $ 2,704 $ 2,521 ___ |
Schedule of Maturities of Long-term Debt | -term debt maturities at Exelon, Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE in the periods 2019 through 2023 and thereafter are as follows: Year Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE 2019 $ 1,349 $ 906 $ 300 $ — $ — $ 125 $ 15 $ 91 $ 18 2020 3,528 2,108 500 — — 20 — — 20 2021 1,511 1 350 300 300 261 1 — 260 2022 3,084 1,024 — 350 250 310 310 — — 2023 850 — — 50 300 500 — 500 — Thereafter 24,979 (a) 4,720 7,243 (b) 2,609 (c) 2,050 4,420 2,425 913 898 Total $ 35,301 $ 8,759 $ 8,393 $ 3,309 $ 2,900 $ 5,636 $ 2,751 $ 1,504 $ 1,196 __________ (a) Includes $390 million due to ComEd and PECO financing trusts. (b) Includes $206 million due to ComEd financing trust. (c) Includes $184 million due to PECO financing trusts. Jun |
Income Taxes (Tables)
Income Taxes (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Income Tax Disclosure [Abstract] | |
Schedule Of Remeasurements Of Deferred Income Taxes Due To Tax Reform [Table Text Block] | The one-time impacts recorded by the Registrants to remeasure their deferred income tax balances at the 21% corporate federal income tax rate as of December 31, 2017 are presented below: Successor Exelon (b) Generation ComEd PECO BGE PHI Pepco DPL ACE Net Decrease to Deferred Income Tax Liability Balances $8,624 $1,895 $2,819 $1,407 $1,120 $1,944 $968 $540 $456 Successor Exelon Generation ComEd PECO (c) BGE PHI Pepco DPL ACE Net Regulatory Liability Recorded (a) $7,315 N/A $2,818 $1,394 $1,124 $1,979 $976 $545 $458 Successor Exelon (b) Generation ComEd PECO BGE PHI Pepco DPL ACE Net Deferred Income Tax Benefit/(Expense) Recorded $1,309 $1,895 $1 $13 $(4) $(35) $(8) $(5) $(2) __________ (a) Reflects the net regulatory liabilities recorded on a pre-tax basis before taking into consideration the income tax benefits associated with the ultimate settlement with customers. (b) Amounts do not sum across due to deferred tax adjustments recorded at the Exelon Corporation parent company, primarily related to certain employee compensation plans. (c) Given the regulatory treatment of income tax benefits related to electric and gas distribution repairs, PECO remained in an overall net regulatory asset position as of December 31, 2017 after recording the impacts related to the TCJA. |
ScheduleOfCategorizationOfNetRegulatoryLiabilitiesDueToTaxReform [Table Text Block] | The table below sets forth the Registrants’ estimated categorization of their net regulatory liabilities as of December 31, 2017. The amounts in the table below are shown on an after-tax basis reflecting future net cash outflows after taking into consideration the income tax benefits associated with the ultimate settlement with customers. Successor Exelon ComEd PECO (a) BGE PHI PEPCO DPL ACE Subject to IRS Normalization Rules $3,040 $1,400 $533 $459 $648 $299 $195 $153 Subject to Rate Regulator Determination 1,694 573 43 324 754 391 194 170 Net Regulatory Liabilities $4,734 $1,973 $576 $783 $1,402 $690 $389 $ 323 _________ (a) Given the regulatory treatment of income tax benefits related to electric and gas distribution repairs, PECO was in an overall net regulatory asset position as of December 31, 2017 after recording the impacts related to the TCJA. As a result, the amount of customer benefits resulting from the TCJA subject to the discretion of PECO's rate regulators are lower relative to the other Utility Registrants. |
Schedule of Components of Income Tax Expense (Benefit) | Income tax expense (benefit) from continuing operations is comprised of the following components: For the Year Ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Included in operations: Federal Current $ 226 $ 337 $ (63 ) $ 11 $ (5 ) $ (4 ) $ 28 $ (3 ) $ (14 ) Deferred (98 ) (347 ) 145 10 47 24 (21 ) 13 18 Investment tax credit amortization (24 ) (21 ) (2 ) — — (1 ) — — — State Current (1 ) 6 (29 ) 1 — 7 — — — Deferred 17 (83 ) 117 (16 ) 32 9 6 12 8 Total $ 120 $ (108 ) $ 168 $ 6 $ 74 $ 35 $ 13 $ 22 $ 12 For the Year Ended December 31, 2017 (a) Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Included in operations: Federal Current $ 194 $ 584 $ (191 ) $ 71 $ 74 $ (60 ) $ (20 ) $ (24 ) $ (12 ) Deferred (471 ) (2,005 ) 523 28 101 250 114 82 34 Investment tax credit amortization (25 ) (21 ) (2 ) — (1 ) (1 ) — — — State Current 14 65 (49 ) 14 (5 ) (4 ) (2 ) — — Deferred 162 1 136 (9 ) 49 32 13 13 4 Total $ (126 ) $ (1,376 ) $ 417 $ 104 $ 218 $ 217 $ 105 $ 71 $ 26 Successor Predecessor For the Year Ended December 31, 2016 (a) March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Included in operations: Federal Current $ 60 $ 513 $ (135 ) $ 63 $ 51 $ (118 ) $ (88 ) $ (26 ) $ (281 ) $ — Deferred 600 (254 ) 379 72 88 136 97 22 283 10 Investment tax credit amortization (24 ) (20 ) (2 ) — (1 ) — — — (1 ) — State Current 39 45 (4 ) 9 5 7 1 — (11 ) — Deferred 78 (2 ) 63 5 31 16 12 — 13 7 Total $ 753 $ 282 $ 301 $ 149 $ 174 $ 41 $ 22 $ (4 ) $ 3 $ 17 The following tables represent the net interest and penalties receivable (payable), including interest and penalties related to tax positions reflected in the Registrants’ Consolidated Balance Sheets. Net interest receivable (payable) as of Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE December 31, 2018 $ 236 $ (2 ) $ 4 $ — $ — $ 1 $ — $ — $ — December 31, 2017 233 (3 ) 4 — — 2 — — — Net penalties payable as of Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE December 31, 2018 $ (17 ) $ — $ — $ — $ — $ — $ — $ — $ — December 31, 2017 (17 ) — — — — — — — — |
Effective Income Tax Rate Reconciliation | The effective income tax rate from continuing operations varies from the U.S. federal statutory rate principally due to the following: For the Year Ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % 21.0 % Increase (decrease) due to: State income taxes, net of Federal income tax benefit 0.6 (16.6 ) 8.3 (2.6 ) 6.6 3.0 2.2 6.7 7.4 Qualified NDT fund income (1.9 ) (11.8 ) — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (1.2 ) (6.5 ) (0.2 ) (0.1 ) (0.1 ) (0.2 ) (0.1 ) (0.3 ) (0.4 ) Plant basis differences (3.5 ) — (0.2 ) (14.1 ) (1.3 ) (1.6 ) (2.7 ) (0.3 ) (0.5 ) Production tax credits and other credits (2.2 ) (13.5 ) — — — — — — — Noncontrolling interests (1.0 ) (6.1 ) — — — — — — — Excess deferred tax amortization (8.3 ) — (9.1 ) (3.2 ) (8.0 ) (14.5 ) (14.8 ) (12.0 ) (14.9 ) Tax Cuts and Jobs Act of 2017 0.9 2.7 (0.1 ) — — 0.1 — — — Other 1.0 1.3 0.5 0.3 0.9 0.3 0.2 0.4 1.2 Effective income tax rate 5.4 % (29.5 )% 20.2 % 1.3 % 19.1 % 8.1 % 5.8 % 15.5 % 13.8 % For the Year Ended December 31, 2017 (a) Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE U.S. Federal statutory rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % Increase (decrease) due to: State income taxes, net of Federal income tax benefit 2.3 2.9 5.7 0.6 5.4 4.8 3.2 5.4 5.6 Qualified NDT fund income 3.8 9.9 — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (0.9 ) (2.1 ) (0.2 ) (0.1 ) (0.1 ) (0.2 ) (0.1 ) (0.2 ) (0.4 ) Plant basis differences (b) (1.7 ) — 0.3 (13.8 ) 0.1 1.1 (0.4 ) 2.0 3.6 Production tax credits and other credits (1.8 ) (4.7 ) — — — — — — — Like-kind exchange (1.2 ) — 1.3 — — — — — — Merger expenses (3.6 ) (1.2 ) — — — (9.5 ) (6.3 ) (7.8 ) (19.8 ) FitzPatrick bargain purchase gain (2.2 ) (5.6 ) — — — — — — — Tax Cuts and Jobs Act of 2017 (c) (33.1 ) (128.3 ) 0.1 (2.3 ) 0.9 6.4 2.7 2.5 1.6 Other 0.1 (0.5 ) 0.2 (0.1 ) 0.2 (0.1 ) (0.2 ) 0.1 (0.4 ) Effective income tax rate (3.3 )% (94.6 )% 42.4 % 19.3 % 41.5 % 37.5 % 33.9 % 37.0 % 25.2 % Successor Predecessor For the Year Ended December 31, 2016 (a) March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL (d) ACE (d) PHI (d) PHI U.S. Federal statutory rate 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % 35.0 % Increase (decrease) due to: State income taxes, net of Federal income tax benefit (e) 3.3 3.2 5.6 1.3 5.0 15.7 52.7 6.2 5.8 11.9 Qualified NDT fund income 3.4 7.9 — — — — — — — — Amortization of investment tax credit, including deferred taxes on basis difference (1.2 ) (2.3 ) (0.3 ) (0.1 ) (0.1 ) (0.2 ) (3.7 ) 0.8 1.4 (0.9 ) Plant basis differences (4.9 ) — (0.6 ) (9.6 ) (2.7 ) (22.8 ) (25.5 ) 10.3 39.0 (13.5 ) Production tax credits and other credits (3.6 ) (8.3 ) — — — — — — — — Noncontrolling interests (0.2 ) (0.6 ) — — — — — — — — Statute of limitations expiration (0.4 ) (1.7 ) — — — — — — — — Penalties 1.9 — 4.5 — — — — — (0.7 ) — Merger Expenses 5.6 1.1 — — — 23.5 112.9 (44.9 ) (89.0 ) 11.1 Other (f) (0.7 ) (1.4 ) 0.1 (1.2 ) — (1.8 ) (2.2 ) 1.3 3.3 3.6 Effective income tax rate 38.2 % 32.9 % 44.3 % 25.4 % 37.2 % 49.4 % 169.2 % 8.7 % (5.2 )% 47.2 % __________ (a) Exelon retrospectively adopted the new standard Revenue from Contracts with Customers. The standard was adopted as of January 1, 2018. The effective income tax rates are recast to reflect the impact of the new standard. (b) Includes the charges related to the transmission-related income tax regulatory asset for Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE of $ 35 million , $ 3 million , $ 5 million , $ 27 million , $ 14 million , $ 6 million and $ 7 million , respectively. See Note 4 - Regulatory Matters for additional information. (c) Included are impacts for TCJA other than the corporate rate change, including revisions further limiting tax deductions for compensation of certain highest paid executives, the write-off of foreign tax credit carryforwards, and loss of a 2015 domestic production activities deduction due to an NOL carryback. (d) DPL and ACE recognized a loss before income taxes for the year ended December 31, 2016, and PHI recognized a loss before income taxes for the period of March 24, 2016, through December 31, 2016. As a result, positive percentages represent an income tax benefit for the periods presented. (e) Includes a remeasurement of uncertain state income tax positions for Pepco and DPL. (f) At PECO, includes a cumulative adjustment related to an anticipated gas repairs tax return accounting method change. The method change request was filed and accepted in 2017. No change to the results recorded as of December 31, 2016. |
Tax Effects of Temporary Differences | Tax Differences and Carryforwards The tax effects of temporary differences and carryforwards, which give rise to significant portions of the deferred tax assets (liabilities), as of December 31, 2018 and 2017 are presented below: As of December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Plant basis differences $ (12,533 ) $ (2,495 ) $ (4,059 ) $ (1,862 ) $ (1,399 ) $ (2,577 ) $ (1,148 ) $ (743 ) $ (645 ) Accrual based contracts 117 (44 ) — — — 161 — — — Derivatives and other financial instruments 89 35 69 — — 3 — — — Deferred pension and postretirement obligation 1,435 (188 ) (255 ) (26 ) (26 ) (102 ) (78 ) (46 ) (14 ) Nuclear decommissioning activities (351 ) (351 ) — — — — — — — Deferred debt refinancing costs 234 23 (7 ) — (3 ) 187 (4 ) (2 ) (1 ) Regulatory assets and liabilities (749 ) — 300 (129 ) 172 (90 ) 58 96 83 Tax loss carryforward 237 78 — 18 25 96 12 52 26 Tax credit carryforward 811 816 — — — — — — — Investment in partnerships (797 ) (775 ) — — — — — — — Other, net 934 239 151 67 12 196 98 17 19 Deferred income tax liabilities (net) $ (10,573 ) $ (2,662 ) $ (3,801 ) $ (1,932 ) $ (1,219 ) $ (2,126 ) $ (1,062 ) $ (626 ) $ (532 ) Unamortized investment tax credits (724 ) (700 ) (12 ) (1 ) (3 ) (8 ) (2 ) (2 ) (3 ) Total deferred income tax liabilities (net) and unamortized investment tax credits $ (11,297 ) $ (3,362 ) $ (3,813 ) $ (1,933 ) $ (1,222 ) $ (2,134 ) $ (1,064 ) $ (628 ) $ (535 ) As of December 31, 2017 (a) Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Plant basis differences $ (12,490 ) $ (2,819 ) $ (3,825 ) $ (1,762 ) $ (1,368 ) $ (2,521 ) $ (1,152 ) $ (717 ) $ (607 ) Accrual based contracts 150 (66 ) — — — 216 — — — Derivatives and other financial instruments (85 ) (66 ) (2 ) — — 3 — — — Deferred pension and postretirement obligation 1,463 (205 ) (285 ) (15 ) (29 ) (130 ) (78 ) (51 ) (18 ) Nuclear decommissioning activities (553 ) (553 ) — — — — — — — Deferred debt refinancing costs 217 26 (8 ) (1 ) (3 ) 203 (4 ) (2 ) (1 ) Regulatory assets and liabilities (688 ) — 489 (90 ) 136 (184 ) 39 88 86 Tax loss carryforward 344 76 33 9 11 156 40 68 35 Tax credit carryforward 861 868 1 — — 6 — — — Investment in partnerships (434 ) (416 ) — — — — — — — Other, net 746 78 141 71 13 193 94 14 16 Deferred income tax liabilities (net) $ (10,469 ) $ (3,077 ) $ (3,456 ) $ (1,788 ) $ (1,240 ) $ (2,058 ) $ (1,061 ) $ (600 ) $ (489 ) Unamortized investment tax credits (732 ) (705 ) (13 ) (1 ) (4 ) (8 ) (2 ) (3 ) (4 ) Total deferred income tax liabilities (net) and unamortized investment tax credits $ (11,201 ) $ (3,782 ) $ (3,469 ) $ (1,789 ) $ (1,244 ) $ (2,066 ) $ (1,063 ) $ (603 ) $ (493 ) |
Summary of Loss Carryforwards | As of December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Plant basis differences $ (12,533 ) $ (2,495 ) $ (4,059 ) $ (1,862 ) $ (1,399 ) $ (2,577 ) $ (1,148 ) $ (743 ) $ (645 ) Accrual based contracts 117 (44 ) — — — 161 — — — Derivatives and other financial instruments 89 35 69 — — 3 — — — Deferred pension and postretirement obligation 1,435 (188 ) (255 ) (26 ) (26 ) (102 ) (78 ) (46 ) (14 ) Nuclear decommissioning activities (351 ) (351 ) — — — — — — — Deferred debt refinancing costs 234 23 (7 ) — (3 ) 187 (4 ) (2 ) (1 ) Regulatory assets and liabilities (749 ) — 300 (129 ) 172 (90 ) 58 96 83 Tax loss carryforward 237 78 — 18 25 96 12 52 26 Tax credit carryforward 811 816 — — — — — — — Investment in partnerships (797 ) (775 ) — — — — — — — Other, net 934 239 151 67 12 196 98 17 19 Deferred income tax liabilities (net) $ (10,573 ) $ (2,662 ) $ (3,801 ) $ (1,932 ) $ (1,219 ) $ (2,126 ) $ (1,062 ) $ (626 ) $ (532 ) Unamortized investment tax credits (724 ) (700 ) (12 ) (1 ) (3 ) (8 ) (2 ) (2 ) (3 ) Total deferred income tax liabilities (net) and unamortized investment tax credits $ (11,297 ) $ (3,362 ) $ (3,813 ) $ (1,933 ) $ (1,222 ) $ (2,134 ) $ (1,064 ) $ (628 ) $ (535 ) As of December 31, 2017 (a) Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Plant basis differences $ (12,490 ) $ (2,819 ) $ (3,825 ) $ (1,762 ) $ (1,368 ) $ (2,521 ) $ (1,152 ) $ (717 ) $ (607 ) Accrual based contracts 150 (66 ) — — — 216 — — — Derivatives and other financial instruments (85 ) (66 ) (2 ) — — 3 — — — Deferred pension and postretirement obligation 1,463 (205 ) (285 ) (15 ) (29 ) (130 ) (78 ) (51 ) (18 ) Nuclear decommissioning activities (553 ) (553 ) — — — — — — — Deferred debt refinancing costs 217 26 (8 ) (1 ) (3 ) 203 (4 ) (2 ) (1 ) Regulatory assets and liabilities (688 ) — 489 (90 ) 136 (184 ) 39 88 86 Tax loss carryforward 344 76 33 9 11 156 40 68 35 Tax credit carryforward 861 868 1 — — 6 — — — Investment in partnerships (434 ) (416 ) — — — — — — — Other, net 746 78 141 71 13 193 94 14 16 Deferred income tax liabilities (net) $ (10,469 ) $ (3,077 ) $ (3,456 ) $ (1,788 ) $ (1,240 ) $ (2,058 ) $ (1,061 ) $ (600 ) $ (489 ) Unamortized investment tax credits (732 ) (705 ) (13 ) (1 ) (4 ) (8 ) (2 ) (3 ) (4 ) Total deferred income tax liabilities (net) and unamortized investment tax credits $ (11,201 ) $ (3,782 ) $ (3,469 ) $ (1,789 ) $ (1,244 ) $ (2,066 ) $ (1,063 ) $ (603 ) $ (493 ) __________ (a) Includes remeasurement impacts related to the TCJA. The following table provides the Registrants’ carryforwards and any corresponding valuation allowances as of December 31, 2018 : Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Federal Federal general business credits carryforwards 811 (a) 816 — — — — — — — State State net operating losses 4,103 (b) 1,544 (b) — 224 (c) 395 (d) 1,492 (e) 192 (f) 772 (g) 365 (h) Deferred taxes on state tax attributes (net) 272 104 — 18 26 102 12 52 26 Valuation allowance on state tax attributes 35 26 — — 1 6 — — — __________ (a) Exelon’s federal general business credit carryforwards will begin expiring in 2033. (b) Exelon’s and Generation's state net operating losses and credit carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2019. (c) PECO's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2031. (d) BGE's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2026. (e) PHI's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2036. (f) Pepco's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2033. (g) DPL's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2030. (h) ACE's state net operating loss carryforwards, which are presented on a post-apportioned basis, will begin expiring in 2031. |
Reconciliation of Unrecognized Tax Benefits Excluding Amounts Pertaining to Examined Tax Returns Foll Forward | The following tables provide a reconciliation of the Registrants’ unrecognized tax benefits as of December 31, 2018 , 2017 and 2016 : Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Unrecognized tax benefits at January 1, 2018 $ 743 $ 468 $ 2 $ — $ 120 $ 125 $ 59 $ 21 $ 14 Change to positions that only affect timing 15 15 — — — — — — — Increases based on tax positions prior to 2018 30 21 — — — 8 7 1 — Decreases based on tax positions prior to 2018 (251 ) (36 ) — — (120 ) (88 ) (66 ) (22 ) — Decrease from settlements with taxing authorities (53 ) (53 ) — — — — — — — Decreases from expiration of statute of limitations (7 ) (7 ) — — — — — — — Unrecognized tax benefits at December 31, 2018 $ 477 $ 408 $ 2 $ — $ — $ 45 $ — $ — $ 14 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Unrecognized tax benefits at January 1, 2017 $ 916 $ 490 $ (12 ) $ — $ 120 $ 172 $ 80 $ 37 $ 22 Increases based on tax positions prior to 2017 28 — 14 — — 14 — — 14 Decreases based on tax positions prior to 2017 (196 ) (17 ) — — — (61 ) (21 ) (16 ) (22 ) Decrease from settlements with taxing authorities (5 ) (5 ) — — — — — — — Unrecognized tax benefits at December 31, 2017 $ 743 $ 468 $ 2 $ — $ 120 $ 125 $ 59 $ 21 $ 14 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Unrecognized tax benefits at January 1, 2016 $ 1,078 $ 534 $ 142 $ — $ 120 $ 22 $ 8 $ 3 $ — Merger balance transfer 22 5 — — — (5 ) — — — Increases based on tax positions related to 2016 108 10 — — — 59 21 16 22 Change to positions that only affect timing (332 ) (12 ) (154 ) — — — — — — Increases based on tax positions prior to 2016 88 — — — — 96 51 18 — Decreases based on tax positions prior to 2016 (21 ) (20 ) — — — — — — — Decreases from settlements with taxing authorities (27 ) (27 ) — — — — — — — Unrecognized tax benefits at December 31, 2016 $ 916 $ 490 $ (12 ) $ — $ 120 $ 172 $ 80 $ 37 $ 22 |
Interest Income and Interest Expense Disclosure [Table Text Block] | The following tables set forth the net interest and penalty expense, including interest and penalties related to tax positions, recognized in Interest expense, net and Other, net in Other income and deductions in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. Net interest expense (income) for the years ended Exelon Generation ComEd PECO BGE Pepco DPL ACE December 31, 2018 $ (3 ) $ — $ — $ — $ — $ — $ — $ — December 31, 2017 37 (1 ) 11 — — — — — December 31, 2016 165 (13 ) 117 — — 6 — (1 ) Net penalty expense (income) for the years ended Exelon Generation ComEd PECO BGE Pepco DPL ACE December 31, 2018 $ — $ — $ — $ — $ — $ — $ — $ — December 31, 2017 (2 ) — — — — — — — December 31, 2016 106 — 86 — — — — — Successor Predecessor PHI December 31, 2018 December 31, 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Net interest expense $ — $ — $ (2 ) $ — |
Summary of Open Tax Years by Jurisdiction | Description of tax years open to assessment by major jurisdiction Taxpayer Open Years Exelon (and predecessors) and subsidiaries consolidated federal income tax returns 1999, 2001-2017 PHI Holdings and subsidiaries consolidated federal income tax returns 2013, 2015-2016 Exelon and subsidiaries Illinois unitary income tax returns 2010-2017 Constellation combined New York corporate income tax returns 2010-March 2012 Exelon combined New York corporate income tax returns 2011-2017 Exelon New Jersey corporate income tax returns 2013-2017 Exelon Pennsylvania corporate net income tax returns 2011-2017 PECO Pennsylvania separate company returns 2015-2017 DPL Delaware separate company returns Same as federal ACE New Jersey separate company returns 2014-2017 Exelon and subsidiaries District of Columbia corporate income tax returns 2015-2017 PHI Holdings and subsidiaries District of Columbia corporate income tax returns 2015-2016 Various separate company Maryland corporate net income tax returns Same as federal |
Asset Retirement Obligations (T
Asset Retirement Obligations (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Asset Retirement Obligation Disclosure [Abstract] | |
Nuclear Decommissioning Asset Retirement Obligation Rollforward | The following table provides a rollforward of the non-nuclear AROs reflected in the Registrants’ Consolidated Balance Sheets from January 1, 2017 to December 31, 2018 : Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Non-nuclear AROs at January 1, 2017 $ 393 $ 199 $ 121 $ 28 $ 24 $ 14 $ 2 $ 9 $ 3 Net (decrease) increase due to changes in, and timing of, estimated future cash flows (11 ) (1 ) (13 ) (1 ) 2 2 1 1 — Development projects 1 1 — — — — — — — Accretion expense (a) 18 10 7 1 — — — — — Deconsolidation of EGTP (7 ) (7 ) — — — — — — — Payments (10 ) (5 ) (2 ) (1 ) (2 ) — — — — Non-nuclear AROs at December 31, 2017 384 197 113 27 24 16 3 10 3 Net increase due to changes in, and timing of, estimated future cash flows (b) 80 35 7 — 2 36 34 1 1 Accretion expense (a) 16 10 4 1 1 — — — — Asset divestitures (3 ) (3 ) — — — — — — — Payments (6 ) (1 ) (3 ) — (2 ) — — — — Non-nuclear AROs at December 31, 2018 $ 471 $ 238 $ 121 $ 28 $ 25 $ 52 $ 37 $ 11 $ 4 __________ (a) For ComEd and PECO, the majority of the accretion is recorded as an increase to a regulatory asset due to the associated regulatory treatment. (b) In 2018, Pepco recorded an increase of $22 million in Operating and maintenance expense primarily related to asbestos identified at its Buzzard Point property as part of an annual ARO study. Buzzard Point is a waterfront property in the District of Columbia occupied by an active substation and former Pepco operated steam plant building, which Pepco retired and closed in 1981. The following table provides a rollforward of the nuclear decommissioning ARO reflected in Exelon’s and Generation’s Consolidated Balance Sheets, from January 1, 2017 to December 31, 2018 : Nuclear decommissioning ARO at January 1, 2017 $ 8,734 Accretion expense 458 Acquisition of FitzPatrick 444 Net increase due to changes in, and timing of, estimated future cash flows 34 Costs incurred related to decommissioning plants (8 ) Nuclear decommissioning ARO at December 31, 2017 (a) 9,662 Accretion expense 478 Net decrease due to changes in, and timing of, estimated future cash flows (77 ) Costs incurred related to decommissioning plants (58 ) Nuclear decommissioning ARO at December 31, 2018 (a) (b) $ 10,005 __________ (a) Includes $22 million and $13 million as the current portion of the ARO at December 31, 2018 and 2017 , respectively, which is included in Other current liabilities in Exelon’s and Generation’s Consolidated Balance Sheets. |
Unrealized Gains Losses On Nuclear Decommissioning Trust Funds | The following table provides unrealized (losses) gains on NDT funds of Exelon and Generation for the years ended 2018 , 2017 and 2016 : 2018 2017 2016 Net unrealized (losses) gains on NDT funds—Regulatory Agreement Units (a) $ (715 ) $ 455 $ 216 Net unrealized (losses) gains on NDT funds—Non-Regulatory Agreement Units (b) (483 ) 521 194 __________ (a) Net unrealized (losses) gains related to Generation’s NDT funds associated with Regulatory Agreement Units are included in Regulatory liabilities in Exelon’s Consolidated Balance Sheets and Noncurrent payables to affiliates in Generation’s Consolidated Balance Sheets. (b) Net unrealized (losses) gains related to Generation’s NDT funds with Non-Regulatory Agreement Units are included within Other, net in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income. |
Nuclear Decommissioning Pledged Assets | The following table provides Exelon's and Generation's pledged assets and payables to ZionSolutions, and withdrawals by ZionSolutions at December 31, 2018 and 2017 : 2018 2017 Carrying value of Zion Station pledged assets $ 9 $ 39 Current payable to ZionSolutions (a) 9 37 Cumulative withdrawals by ZionSolutions to pay decommissioning costs (b) 965 942 _______ (a) Included in Other current liabilities within Exelon's and Generation's Consolidated Balance Sheets. Excludes a liability recorded within Exelon’s and Generation’s Consolidated Balance Sheets related to the tax obligation on the unrealized gains and losses associated with the Zion Station NDT funds. The NDT funds will be utilized to satisfy the tax obligations as gains and losses are realized. (b) Includes project expenses to decommission Zion Station and estimated tax payments on Zion Station NDT fund earnings. |
Retirement Benefits (Tables)
Retirement Benefits (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Retirement Benefits [Abstract] | |
Schedule Of Pension And Other Postretirement Participation | The table below shows the pension and other postretirement benefit plans in which employees of each operating company participated at December 31, 2018 : Operating Company (e) Name of Plan: Generation ComEd PECO BGE BSC PHI Pepco DPL ACE Qualified Pension Plans: Exelon Corporation Retirement Program (a) X X X X X X X Exelon Corporation Cash Balance Pension Plan (a) X X X X X X X X X Exelon Corporation Pension Plan for Bargaining Unit Employees (a) X X X Exelon New England Union Employees Pension Plan (a) X Exelon Employee Pension Plan for Clinton, TMI and Oyster Creek (a) X X X X Pension Plan of Constellation Energy Group, Inc. (b) X X X X X X X Pension Plan of Constellation Energy Nuclear Group, LLC (c) X X X X X Nine Mile Point Pension Plan (c) X X Constellation Mystic Power, LLC Union Employees Pension Plan Including Plan A and Plan B (b) X Pepco Holdings LLC Retirement Plan (d) X X X X X X X X X Non-Qualified Pension Plans: Exelon Corporation Supplemental Pension Benefit Plan and 2000 Excess Benefit Plan (a) X X X X X Exelon Corporation Supplemental Management Retirement Plan (a) X X X X X X Constellation Energy Group, Inc. Senior Executive Supplemental Plan (b) X X X Constellation Energy Group, Inc. Supplemental Pension Plan (b) X X X Constellation Energy Group, Inc. Benefits Restoration Plan (b) X X X X X Constellation Energy Nuclear Plan, LLC Executive Retirement Plan (c) X X Constellation Energy Nuclear Plan, LLC Benefits Restoration Plan (c) X X Baltimore Gas & Electric Company Executive Benefit Plan (b) X X X Baltimore Gas & Electric Company Manager Benefit Plan (b) X X X X Pepco Holdings LLC 2011 Supplemental Executive Retirement Plan (d) X X X X X Conectiv Supplemental Executive Retirement Plan (d) X X X X X Pepco Holdings LLC Combined Executive Retirement Plan (d) X X X Atlantic City Electric Director Retirement Plan (d) X Operating Company (e) Name of Plan: Generation ComEd PECO BGE BSC PHI Pepco DPL ACE Other Postretirement Benefit Plans: PECO Energy Company Retiree Medical Plan (a) X X X X X X X X X Exelon Corporation Health Care Program (a) X X X X X X X X Exelon Corporation Employees’ Life Insurance Plan (a) X X X X X Exelon Corporation Health Reimbursement Arrangement Plan (a) X X X X X Constellation Energy Group, Inc. Retiree Medical Plan (b) X X X X X Constellation Energy Group, Inc. Retiree Dental Plan (b) X X X Constellation Energy Group, Inc. Employee Life Insurance Plan and Family Life Insurance Plan (b) X X X X X Constellation Mystic Power, LLC Post-Employment Medical Account Savings Plan (b) X Exelon New England Union Post-Employment Medical Savings Account Plan (a) X Retiree Medical Plan of Constellation Energy Nuclear Group LLC (c) X X X Retiree Dental Plan of Constellation Energy Nuclear Group LLC (c) X X X Nine Mile Point Nuclear Station, LLC Medical Care and Prescription Drug Plan for Retired Employees (c) X X Pepco Holdings LLC Welfare Plan for Retirees (d) X X X X X X X X X ______________________ (a) These plans are collectively referred to as the legacy Exelon plans. (b) These plans are collectively referred to as the legacy Constellation Energy Group (CEG) Plans. (c) These plans are collectively referred to as the legacy CENG plans. (d) These plans are collectively referred to as the legacy PHI plans. (e) Employees generally remain in their legacy benefit plans when transferring between operating companies. |
Defined Benefit Plan Change In Benefit Obligation RollForward | The following tables provide a rollforward of the changes in the benefit obligations and plan assets for the most recent two years for all plans combined: Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2018 2017 Change in benefit obligation: Net benefit obligation at beginning of year $ 22,337 $ 21,060 $ 4,856 $ 4,457 Service cost 405 387 112 106 Interest cost 802 842 175 182 Plan participants’ contributions — — 45 53 Actuarial (gain) loss (a) (1,561 ) 1,182 (540 ) 350 Plan amendments (4 ) 9 — — Acquisitions (b) — 16 — 17 Settlements (48 ) (34 ) (4 ) — Gross benefits paid (1,239 ) (1,125 ) (275 ) (309 ) Net benefit obligation at end of year $ 20,692 $ 22,337 $ 4,369 $ 4,856 Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2018 2017 Change in plan assets: Fair value of net plan assets at beginning of year $ 18,573 $ 16,791 $ 2,732 $ 2,578 Actual return on plan assets (945 ) 2,600 (136 ) 346 Employer contributions 337 341 46 64 Plan participants’ contributions — — 45 53 Gross benefits paid (1,239 ) (1,125 ) (275 ) (309 ) Settlements (48 ) (34 ) (4 ) — Fair value of net plan assets at end of year $ 16,678 $ 18,573 $ 2,408 $ 2,732 __________ (a) The pension actuarial gain in 2018 primarily reflects an increase in the discount rate. The OPEB actuarial gain in 2018 primarily reflects an increase in the discount rate and favorable health care claims experience. The pension and OPEB actuarial losses in 2017 primarily reflect a decrease in the discount rate. (b) Exelon recorded pension and OPEB obligations associated with its acquisition of Fitzpatrick on March 31, 2017. |
Schedule of Amounts Recognized in Balance Sheet | Exelon presents its benefit obligations and plan assets net on its balance sheet within the following line items: Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2018 2017 Other current liabilities $ 26 $ 28 $ 33 $ 31 Pension obligations 3,988 3,736 — — Non-pension postretirement benefit obligations — — 1,928 2,093 Unfunded status (net benefit obligation less plan assets) $ 4,014 $ 3,764 $ 1,961 $ 2,124 |
Schedule of Defined Benefit Plans Disclosures | The following tables present the components of Exelon’s net periodic benefit costs, prior to capitalization, for the years ended December 31, 2018 , 2017 and 2016 and PHI's net periodic benefit costs, prior to capitalization, for the predecessor period of January 1, 2016 to March 23, 2016 . Pension Benefits Other Postretirement Benefits Exelon 2018 2017 (a) 2016 (b) 2018 2017 (a) 2016 (b) Components of net periodic benefit cost: Service cost $ 405 $ 387 $ 354 $ 112 $ 106 $ 107 Interest cost 802 842 830 175 182 185 Expected return on assets (1,252 ) (1,196 ) (1,141 ) (173 ) (162 ) (162 ) Amortization of: Prior service cost (credit) 2 1 14 (186 ) (188 ) (185 ) Actuarial loss 629 607 554 66 61 63 Settlement and other charges (c) 3 3 2 1 — — Net periodic benefit cost $ 589 $ 644 $ 613 $ (5 ) $ (1 ) $ 8 __________ (a) FitzPatrick net benefit costs are included for the period after acquisition. (b) PHI net periodic benefit costs for the period prior to the merger are not included in the table above. (c) 2016 amount includes an additional termination benefit for PHI. Predecessor Pension Benefits Other PHI January 1, 2016 to March 23, 2016 January 1, 2016 to March 23, 2016 Components of net periodic benefit cost: Service cost $ 12 $ 1 Interest cost 26 6 Expected return on assets (30 ) (5 ) Amortization of: Prior service cost (credit) — (3 ) Actuarial loss 14 2 Net periodic benefit cost $ 22 $ 1 The following table provides the components of gross accumulated other comprehensive loss and regulatory assets (liabilities) that have not been recognized as components of periodic benefit cost at December 31, 2018 and 2017 , respectively, for all plans combined: Exelon Exelon Pension Benefits Other Postretirement Benefits 2018 2017 2018 2017 Prior service (credit) cost $ (29 ) $ (24 ) $ (337 ) $ (522 ) Actuarial loss 7,558 7,556 531 829 Total $ 7,529 $ 7,532 $ 194 $ 307 Total included in AOCI $ 3,899 $ 3,896 $ 70 $ 125 Total included in regulatory assets (liabilities) $ 3,630 $ 3,636 $ 124 $ 182 |
Changes In Plan Assets And Benefit Obligations Recognized In OCI And Regulatory Assets | The following tables provide the components of AOCI and regulatory assets (liabilities) for the years ended December 31, 2018 , 2017 and 2016 for all plans combined and the components of PHI's predecessor AOCI and regulatory assets (liabilities) for the period January 1, 2016 to March 23, 2016 . Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2016 (a) 2018 2017 2016 (a) Changes in plan assets and benefit obligations recognized in AOCI and regulatory assets (liabilities): Current year actuarial (gain) loss $ 635 $ (222 ) $ 644 $ (232 ) $ 166 $ (101 ) Amortization of actuarial loss (629 ) (607 ) (554 ) (66 ) (61 ) (63 ) Current year prior service cost (credit) (4 ) 9 (60 ) — — — Amortization of prior service (cost) credit (2 ) (1 ) (14 ) 186 188 185 Settlements (3 ) (3 ) — — — — Acquisitions — — 994 — — 94 Total recognized in AOCI and regulatory assets (liabilities) $ (3 ) $ (824 ) $ 1,010 $ (112 ) $ 293 $ 115 Total recognized in AOCI $ 3 $ (401 ) $ 51 $ (55 ) $ 168 $ 20 Total recognized in regulatory assets (liabilities) $ (6 ) $ (423 ) $ 959 $ (57 ) $ 125 $ 95 Predecessor Pension Benefits Other PHI January 1, 2016 to March 23, 2016 January 1, 2016 to March 23, 2016 Changes in plan assets and benefit Current year actuarial loss (gain) $ — $ — Amortization of actuarial loss (14 ) (2 ) Amortization of prior service (cost) credit — 3 Total recognized in AOCI and regulatory assets (liabilities) $ (14 ) $ 1 Total recognized in AOCI $ (1 ) $ — Total recognized in regulatory assets (liabilities) $ (13 ) $ 1 |
Schedule of Amounts in Accumulated Other Comprehensive Income (Loss) to be Recognized over Next Fiscal Year [Table Text Block] | |
Defined Benefit Plan Weighted Average Assumptions Used In Calculating Benefit Obligation [Table Text Block] | The following assumptions were used to determine the benefit obligations for the plans at December 31, 2018 , 2017 and 2016 . Assumptions used to determine year-end benefit obligations are the assumptions used to estimate the subsequent year’s net periodic benefit costs. Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2016 (f) 2018 2017 2016 (f) Discount rate 4.31 % (a) 3.62 % (b) 4.04 % (c) 4.30 % (a) 3.61 % (b) 4.04 % (c) Investment Crediting Rate 4.46 % 4.00 % 4.46 % N/A N/A N/A Rate of compensation increase (d) (d) (e) (d) (d) (e) Mortality table RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) Health care cost trend on covered charges N/A N/A N/A 5.00% with ultimate trend of 5.00% in 2017 5.00% with 5.00% __________ (a) The discount rates above represent the blended rates used to determine the majority of Exelon’s pension and other postretirement benefits obligations as of December 31, 2018 . Certain benefit plans used individual rates ranging from 4.13% - 4.36% and 4.27% - 4.38% for pension and other postretirement plans, respectively. (b) The discount rates above represent the blended rates used to determine the majority of Exelon’s pension and other postretirement benefits obligations as of December 31, 2017 . Certain benefit plans used individual rates ranging from 3.49% - 3.65% and 3.57% - 3.68% for pension and other postretirement plans, respectively. (c) The discount rates above represent the blended rates used to determine the majority of Exelon’s pension and other postretirement benefits obligations as of December 31, 2016 . Certain benefit plans used individual rates ranging from 3.66% - 4.11% and 4.00% - 4.17% for pension and other postretirement plans, respectively. (d) 3.25% through 2019 and 3.75% thereafter. (e) The legacy Exelon, CEG and CENG pension and other postretirement plans used a rate of compensation increase of 3.25% through 2019 and 3.75% thereafter, while the legacy PHI pension and other postretirement plans used a weighted-average rate of compensation increase of 5% for all periods. (f) Obligation was not remeasured for the PHI predecessor for the period from January 1, 2016, to March 23, 2016 |
Defined Benefit Plan Weighted Average Assumptions Used In Calculating Net Periodic Benefit Cost [Table Text Block] | The following assumptions were used to determine the net periodic benefit costs for the plans for the years ended December 31, 2018 , 2017 and 2016 , as well as for the PHI predecessor period January 1, 2016 to March 23, 2016 : Pension Benefits Other Postretirement Benefits Exelon 2018 2017 2016 2018 2017 2016 Discount rate 3.62 % (a) 4.04 % (b) 4.29 % (c) 3.61 % (a) 4.04 % (b) 4.29 % (c) Investment Crediting Rate 4.00 % 4.46 % 5.31 % N/A N/A N/A Expected return on plan assets 7.00 % (d) 7.00 % (d) 7.00 % (d) 6.60 % (d) 6.58 % (d) 6.71 % (d) Rate of compensation increase (f) (f) (e) Mortality table RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) RP-2000 table projected to 2012 with improvement scale AA, with Scale BB-2D improvements (adjusted) Health care cost trend on covered charges N/A N/A N/A 5.00% with ultimate trend of 5.00% in 2017 5.00% 5.50% Predecessor Pension Benefits Other Postretirement Benefits PHI January 1, 2016 to March 23, 2016 January 1, 2016 to March 23, 2016 Discount rate 4.65%/4.55% (g) 4.55 % Investment crediting rate 2.89 % N/A Expected return on plan assets (h) 6.50 % 6.75 % Rate of compensation 5.00 % 5.00 % Mortality table RP-2014 table with improvement scale MP-2015 RP-2014 table with improvement scale MP-2015 Health care cost trend on covered charges N/A 6.33% pre-65 and 5.40% post-65 decreasing to ultimate trend of 5.00% in 2020 __________ (a) The discount rates above represent the blended rates used to establish the majority of Exelon’s pension and other postretirement benefits costs for the year ended December 31, 2018 . Certain benefit plans used individual rates ranging from 3.49% - 3.65% and 3.57% - 3.68% for pension and other postretirement plans, respectively. (b) The discount rates above represent the blended rates used to establish the majority of Exelon's pension and other postretirement benefits costs for the year ended December 31, 2017 . Certain benefit plans used individual rates ranging from 3.66% - 4.11% and 4.00% - 4.17% for pension and other postretirement plans, respectively. (c) The discount rates above represent the blended rates used to establish the majority of Exelon’s pension and other postretirement benefits costs for the year ended December 31, 2016 . Certain benefit plans used the individual rates ranging from 3.68% - 4.14% and 4.32% - 4.43% for pension and other postretirement plans, respectively. (d) Not applicable to pension and other postretirement benefit plans that do not have plan assets. (e) 3.25% through 2019 and 3.75% thereafter. (f) The legacy Exelon, CEG and CENG pension and other postretirement plans used a rate of compensation increase of 3.25% through 2019 and 3.75% thereafter, while the legacy PHI pension and other postretirement plans used a weighted-average rate of compensation increase of 5% for all periods. (g) The discount rate for the qualified and non-qualified pension plans was 4.65% and 4.55% , respectively. (h) Expected return on other postretirement benefit plan assets is pre-tax. |
Pension And Other Postretirement Benefit Contributions [Table Text Block] | s The following tables provide contributions to the pension and other postretirement benefit plans: Pension Benefits Other Postretirement Benefits 2018 (a) 2017 (a) 2016 (a) 2018 2017 2016 Exelon $ 337 $ 341 $ 347 $ 46 $ 64 $ 50 Generation 128 137 140 11 11 12 ComEd 38 36 33 4 5 5 PECO 28 24 30 — — — BGE 40 39 31 14 14 18 BSC (b) 41 38 39 5 2 3 Pepco 6 62 24 11 10 8 DPL — — 22 — 2 — ACE 6 — 15 — 20 2 PHISCO (c) 50 5 17 1 — 2 Pension Benefits Other Postretirement Benefits Successor Predecessor Successor Predecessor 2018 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 2018 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 PHI $ 62 $ 67 $ 74 $ 4 $ 12 $ 32 $ 12 $ — __________ (a) Exelon's and Generation's pension contributions include $21 million and $25 million related to the legacy CENG plans that was funded by CENG as provided in an Employee Matters Agreement (EMA) between Exelon and CENG for the years ended December 31, 2017 and 2016 , respectively. There were no pension contributions for the year ended December 31, 2018 . (b) Includes $2 million , $4 million , and $6 million of pension contributions funded by Exelon Corporate, for the years ended December 31, 2018 , 2017 , and 2016 , respectively. (c) : Qualified Pension Plans Non-Qualified Pension Plans Other Exelon $ 301 $ 25 $ 44 Generation 135 7 13 ComEd 65 1 2 PECO 25 1 — BGE 34 1 15 BSC 41 7 2 PHI 1 8 12 Pepco — 2 10 DPL — 1 — ACE — — 1 PHISCO 1 5 1 |
Schedule of Expected Benefit Payments [Table Text Block] | Estimated Future Benefit Payments Estimated future benefit payments to participants in all of the pension plans and postretirement benefit plans at December 31, 2018 were: Pension Benefits Other Postretirement Benefits 2019 $ 1,196 $ 255 2020 1,221 263 2021 1,258 269 2022 1,284 274 2023 1,302 282 2024 through 2028 6,770 1,483 Total estimated future benefit payments through 2028 $ 13,031 $ 2,826 |
Schedule Of Pension And Other Postretirement Benefit Costs [Table Text Block] | For the Years Ended December 31, Exelon Generation (a) ComEd PECO BGE BSC (b) Pepco (c) DPL (c) ACE (c) PHISCO (c)(d) 2018 $ 583 $ 204 $ 177 $ 18 $ 60 $ 57 $ 15 $ 6 $ 12 $ 34 2017 643 227 176 29 64 53 25 13 13 43 2016 621 218 166 33 68 48 31 18 15 47 Successor Predecessor PHI For the Year Ended December 31, 2018 For the Year Ended December 31, 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Pension and Other Postretirement Benefit Costs $ 67 $ 94 $ 88 $ 23 __________ (a) FitzPatrick net benefit costs are included for the period after acquisition. (b) These amounts primarily represent amounts billed to Exelon’s subsidiaries through intercompany allocations. These amounts are not included in the Generation, ComEd, PECO, BGE, PHI, Pepco, DPL or ACE amounts |
Defined Benefit Plan Weighted Average Asset Allocations And Target Allocations [Table Text Block] | ively. Exelon’s pension and other postretirement benefit plan target asset allocations at December 31, 2018 and 2017 asset allocations were as follows: Pension Plans Exelon Percentage of Plan Assets at December 31, Asset Category Target Allocation 2018 2017 Equity securities 35 % 32 % 35 % Fixed income securities 37 % 38 39 Alternative investments (a) 28 % 30 26 Total 100 % 100 % Other Postretirement Benefit Plans Exelon Percentage of Plan Assets at December 31, Asset Category Target Allocation 2018 2017 Equity securities 47 % 44 % 47 % Fixed income securities 28 % 28 28 Alternative investments (a) 25 % 28 25 Total 100 % 100 % __________ (a) Alternative investments include private equity, hedge funds, real estate, and private credit |
Defined Benefit Plan Fair Value Of Plan Assets [Text Block] | Fair Value Measurements The following tables present pension and other postretirement benefit plan assets measured and recorded at fair value in the Registrants' Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy at December 31, 2018 and 2017 : Exelon December 31, 2018 (a) Level 1 Level 2 Level 3 Not subject to leveling Total Pension plan assets Cash equivalents $ 350 $ — $ — $ — $ 350 Equities (c) 3,364 — 2 1,980 5,346 Fixed income: U.S. Treasury and agencies 996 173 — — 1,169 State and municipal debt — 59 — — 59 Corporate debt — 3,716 216 — 3,932 Other (c) — 329 — 613 942 Fixed income subtotal 996 4,277 216 613 6,102 Private equity — — — 1,219 1,219 Hedge funds — — — 1,608 1,608 Real estate — — — 1,029 1,029 Private credit — — 268 798 1,066 Pension plan assets subtotal $ 4,710 $ 4,277 $ 486 $ 7,247 $ 16,720 December 31, 2018 (a) Level 1 Level 2 Level 3 Not subject to leveling Total Other postretirement benefit plan assets Cash equivalents $ 22 $ — $ — $ — $ 22 Equities 537 2 — 508 1,047 Fixed income: U.S. Treasury and agencies 11 56 — — 67 State and municipal debt — 126 — — 126 Corporate debt — 48 — — 48 Other 183 72 — 170 425 Fixed income subtotal 194 302 — 170 666 Hedge funds — — — 411 411 Real estate — — — 132 132 Private credit — — — 132 132 Other postretirement benefit plan assets subtotal $ 753 $ 304 $ — $ 1,353 $ 2,410 Total pension and other postretirement benefit plan assets (e) $ 5,463 $ 4,581 $ 486 $ 8,600 $ 19,130 December 31, 2017 (a)(b) Level 1 Level 2 Level 3 Not subject to leveling Total Pension plan assets Cash equivalents $ 585 $ — $ — $ — $ 585 Equities (c) 3,565 — 2 3,077 6,644 Fixed income: U.S. Treasury and agencies 1,150 159 — — 1,309 State and municipal debt — 64 — — 64 Corporate debt — 3,931 232 — 4,163 Other (c) — 447 — 756 1,203 Fixed income subtotal 1,150 4,601 232 756 6,739 Private equity — — — 1,034 1,034 Hedge funds — — — 1,770 1,770 Real estate — — — 884 884 Private credit (d) — — 224 695 919 Pension plan assets subtotal $ 5,300 $ 4,601 $ 458 $ 8,216 $ 18,575 December 31, 2017 (a)(b) Level 1 Level 2 Level 3 Not subject to leveling Total Other postretirement benefit plan assets Cash equivalents $ 29 $ — $ — $ — $ 29 Equities 523 2 — 764 1,289 Fixed income: U.S. Treasury and agencies 13 56 — — 69 State and municipal debt — 136 — — 136 Corporate debt — 47 — — 47 Other 225 71 — 185 481 Fixed income subtotal 238 310 — 185 733 Hedge funds — — — 430 430 Real estate — — — 124 124 Private credit — — — 123 123 Other postretirement benefit plan assets subtotal $ 790 $ 312 $ — $ 1,626 $ 2,728 Total pension and other postretirement benefit plan assets (e) $ 6,090 $ 4,913 $ 458 $ 9,842 $ 21,303 __________ (a) See Note 11 — Fair Value of Financial Assets and Liabilities for a description of levels within the fair value hierarchy. (b) Effective March 31, 2017, Exelon became sponsor of FitzPatrick's defined benefit pension and other postretirement benefit plans, and assumed FitzPatrick's benefit plan obligations. (c) Includes derivative instruments of less than $1 million and $6 million , which have a total notional amount of $5,991 million and $3,606 million at December 31, 2018 and 2017 , respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the fiscal years ended and do not represent the amount of the company’s exposure to credit or market loss. (d) Prior year amounts reflect a reclassification from Not subject to leveling into Level 3. (e) Excludes net liabilities of $44 million and net assets of $2 million at December 31, 2018 and 2017 , respectively, which are required to reconcile to the fair value of net plan assets. These items consist primarily of receivables or payables related to pending securities sales and purchases, interest and dividends receivable |
Schedule of Changes in Fair Value of Plan Assets [Table Text Block] | The following table presents the reconciliation of Level 3 assets and liabilities measured at fair value for pension and other postretirement benefit plans for the years ended December 31, 2018 and 2017 : Exelon Fixed Income Equities Private Credit Total Pension Assets Balance as of January 1, 2018 $ 232 $ 2 $ 224 $ 458 Actual return on plan assets: Relating to assets still held at the (14 ) — 9 (5 ) Relating to assets sold during the period (1 ) — — (1 ) Purchases, sales and settlements: Purchases 19 — 35 54 Sales (8 ) — — (8 ) Settlements (b) (12 ) — — (12 ) Balance as of December 31, 2018 $ 216 $ 2 $ 268 $ 486 Fixed income Equities Private Credit (a) Total Pension Assets Balance as of January 1, 2017 $ 206 $ 2 $ 229 $ 437 Actual return on plan assets: Relating to assets still held at the reporting date 11 — 29 40 Purchases, sales and settlements: Purchases 31 — 5 36 Sales (16 ) — — (16 ) Settlements (b) — — (39 ) (39 ) Balance as of December 31, 2017 $ 232 $ 2 $ 224 $ 458 __________ (a) |
Schedule Of Defined Contributions [Table Text Block] | in limits. The following table presents matching contributions to the savings plan for the years ended December 31, 2018 , 2017 and 2016 : For the Year Ended December 31, Exelon (a) Generation (a) ComEd PECO BGE BSC (b) Pepco (c) DPL (c) ACE PHISCO (c)(d) 2018 $ 179 $ 86 $ 37 $ 9 $ 12 $ 22 $ 3 $ 2 $ 2 $ 6 2017 128 55 31 10 10 9 3 2 2 6 2016 164 79 34 10 12 19 3 2 2 6 Successor Predecessor PHI For the Year Ended December 31, 2018 For the Year Ended December 31, 2017 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Saving Plan Matching Contributions $ 13 $ 13 $ 10 $ 3 __________ (a) Includes $13 million related to CENG for the year ended December 31, 2016. (b) These amounts primarily represent amounts billed to Exelon’s subsidiaries through intercompany allocations. These costs are not included in the Generation, ComEd, PECO, BGE, PHI, Pepco, DPL or ACE amounts above. (c) Pepco's, DPL's and PHISCO's matching contributions include $1 million , $1 million and $1 million , respectively, of costs incurred prior to the closing of Exelon's merger with PHI on March 23, 2016, which is not included in Exelon's matching contributions for the year ended December 31, 2016. (d) These amounts primarily represent amounts billed to Pepco, DPL, and ACE through intercompany allocations. These amounts are not included in Pepco, DPL or ACE amounts above. |
Severance (Tables)
Severance (Tables) | 12 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2016 | |
Restructuring and Related Activities [Abstract] | ||
Severance | For the periods ended December 31, 2018 , 2017 and 2016 , the Registrants have recognized costs to achieve the PHI merger as follows: For the Year Ended December 31, Acquisition, Integration and Financing Costs (a) 2018 2017 2016 Exelon $ 7 $ 16 $ 143 Generation 5 22 37 ComEd (b) — 1 (6 ) PECO 1 4 5 BGE (b) 1 4 (1 ) Pepco (b) — (6 ) 28 DPL (b) — (7 ) 20 ACE (b) — (6 ) 19 Successor Predecessor For the Year Ended December 31, March 24, 2016 to December 31, 2016 January 1, 2016 to Acquisition, Integration and Financing Costs (a) 2018 2017 PHI (b) $ — $ (18 ) $ 69 $ 29 ______________ (a) The costs incurred are classified primarily within Operating and maintenance expense in the Registrants’ respective Consolidated Statements of Operations and Comprehensive Income, with the exception of the financing costs, which are included within Interest expense. Costs do not include merger commitments discussed above. (b) For the year ended December 31, 2017 , includes deferrals of previously incurred integration costs as regulatory assets of $24 million , $8 million , $8 million , and $8 million at PHI, Pepco, DPL and ACE, respectively. For the year ended December 31, 2016 , includes deferrals of previously incurred integration costs as regulatory assets of $8 million , $6 million , $11 million and $4 million at ComEd, BGE, Pepco and DPL, respectively. For the Successor period March 24, 2016 to December 31, 2016 , includes deferrals of previously incurred integration costs as regulatory assets of $16 million at PHI. See Note 4 - Regulatory Matters for additional information. | For the year ended December 31, 2016 , the Registrants recorded the following severance costs associated with the identified job reductions within Operating and maintenance expense in their Consolidated Statements of Operations and Comprehensive Income: Severance Benefits Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Severance costs (a) $ 57 $ 9 $ 2 $ 1 $ 1 $ 44 $ 21 $ 13 $ 10 (a) The amounts above for Generation, ComEd, PECO, BGE, Pepco, DPL, and ACE include $8 million , $2 million , $1 million , $1 million , $20 million , $12 million and $10 million , respectively, for amounts billed by BSC and/or PHISCO through intercompany allocations. |
Severance Liability | Amounts included in the table below represent the severance liability recorded for employees of each Registrant. Exelon's severance liability includes amounts related to BSC that are billed through intercompany allocations . Severance Liability Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Balance at December 31, 2016 $ 88 $ 36 $ 3 $ — $ — $ 29 $ — $ — $ — Severance costs (a) 35 31 2 — — 3 — — — Payments (29 ) (9 ) (2 ) — — (12 ) — — — Balance at December 31, 2017 $ 94 $ 58 $ 3 $ — $ — $ 20 $ — $ — $ — Severance costs (a) 35 9 1 — 1 5 1 — — Payments (52 ) (20 ) (2 ) — — (18 ) (1 ) — — Balance at December 31, 2018 $ 77 $ 47 $ 2 $ — $ 1 $ 7 $ — $ — $ — __________ (a) Includes salary continuance and health and welfare severance benefits. |
Shareholders' Equity Sharehold
Shareholders' Equity Shareholder Equity (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Shareholder [Abstract] | |
Schedule of Common Stock Outstanding Roll Forward [Table Text Block] | The following table presents common stock authorized and outstanding as of December 31, 2018 and 2017 : December 31, 2018 2017 Par Value Shares Authorized Shares Outstanding Common Stock Exelon no par value 2,000,000,000 968,187,955 963,335,888 ComEd $ 12.50 250,000,000 127,021,331 127,021,246 PECO no par value 500,000,000 170,478,507 170,478,507 BGE no par value 1,500 1,000 1,000 Pepco $ 0.01 200,000,000 100 100 DPL $ 2.25 1,000 1,000 1,000 ACE $ 3.00 25,000,000 8,546,017 8,546,017 |
Stock-Based Compensation Plan_2
Stock-Based Compensation Plans (All Registrants) (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Common Stock [Abstract] | |
Schedule of Compensation Cost for Share-based Payment Arrangements, Allocation of Share-based Compensation Costs by Plan [Table Text Block] | The following tables present the stock-based compensation expense included in Exelon's and PHI’s Consolidated Statements of Operations and Comprehensive Income for the years ended December 31, 2018 , 2017 and 2016 and PHI's predecessor period January 1, 2016 to March 23, 2016 : Exelon Year Ended December 31, Components of Stock-Based Compensation Expense 2018 2017 2016 (a) Performance share awards $ 143 $ 107 $ 93 Restricted stock units 57 77 75 Stock options — — — Other stock-based awards 8 7 7 Total stock-based compensation expense included in operating and maintenance expense 208 191 175 Income tax benefit (54 ) (74 ) (68 ) Total after-tax stock-based compensation expense $ 154 $ 117 $ 107 __________ (a) 2016 amounts include expense related to stock-based compensation granted to eligible PHI employees since the merger date of March 23, 2016 . PHI Predecessor January 1 to March 23, Components of Stock-Based Compensation Expense 2016 Time-based restricted stock units $ 2 Performance-based restricted stock units 1 Time-based restricted stock awards — Total stock-based compensation expense included in operating and maintenance expense 3 Income tax benefit (1 ) Total after-tax stock-based compensation expense $ 2 |
Disclosure of Share-based Compensation Arrangements by Share-based Payment Award [Table Text Block] | The following tables present the Registrants' stock-based compensation expense (pre-tax) for the years ended December 31, 2018 , 2017 and 2016 , as well as for the PHI predecessor period January 1, 2016 to March 23, 2016 : Year Ended December 31, Subsidiaries 2018 2017 2016 Exelon $ 208 $ 191 $ 175 Generation 77 88 78 ComEd 8 7 8 PECO 5 3 3 BGE 3 1 1 BSC (a) 111 88 81 PHI Successor (b)(c) 4 4 4 Predecessor January 1 to 2016 PHI $ 3 __________ (a) These amounts primarily represent amounts billed to Exelon’s subsidiaries through intercompany allocations. These amounts are not included in the Generation, ComEd, PECO, BGE or PHI amounts above. (b) Pepco's, DPL's and ACE's stock-based compensation expense for the years ended December 31, 2018 and 2017 was not material. (c) These amounts primarily represent amounts billed to PHI’s subsidiaries through PHISCO intercompany allocations. |
Stock Based Compensation Tax Benefit | The following tables present information regarding Exelon’s tax benefits for the years ended December 31, 2018 , 2017 and 2016 . Exelon Year Ended December 31, 2018 2017 2016 Realized tax benefit when exercised/distributed: Restricted stock units 28 35 27 Performance share awards 16 29 18 |
Schedule of Share-based Compensation, Stock Options, Activity | The following table presents information with respect to stock option activity for the year ended December 31, 2018 : Shares Weighted Average Exercise Price (per share) Weighted Average Remaining Contractual Life (years) Aggregate Intrinsic Value Balance of shares outstanding at December 31, 2017 6,723,611 $ 47.69 2.65 $ 7 Options exercised (1,522,952 ) 36.54 Options forfeited — — Options expired (1,173,007 ) 74.99 Balance of shares outstanding at December 31, 2018 4,027,652 $ 43.95 2.90 $ 14 Exercisable at December 31, 2018 (a) 4,027,652 $ 43.95 2.90 $ 14 __________ (a) Includes stock options issued to retirement eligible employees. |
Stock Options Exercised | The following table summarizes additional information regarding stock options exercised for the years ended December 31, 2018 , 2017 and 2016 : Year Ended 2018 2017 2016 Intrinsic value (a) $ 12 $ 15 $ 11 Cash received for exercise price 56 107 19 __________ (a) The difference between the market value on the date of exercise and the option exercise price. |
Schedule of Nonvested Restricted Stock Units Activity | The following table summarizes Exelon’s nonvested restricted stock unit activity for the year ended December 31, 2018 : Exelon Shares Weighted Average Grant Date Fair Value (per share) Nonvested at December 31, 2017 (a) 3,389,503 $ 32.24 Granted 1,321,988 38.60 Vested (1,845,300 ) 32.03 Forfeited (65,046 ) 32.96 Undistributed vested awards (b) (507,804 ) 36.76 Nonvested at December 31, 2018 (a) 2,293,341 $ 35.06 __________ (a) Excludes 1,131,487 and 1,488,383 of restricted stock units issued to retirement-eligible employees as of December 31, 2018 and 2017 , respectively, as they are fully vested. (b) Represents restricted stock units that vested but were not distributed to retirement-eligible employees during 2018 . |
Schedule of Nonvested Performance-based Units Activity | The following table summarizes Exelon’s nonvested performance share awards activity for the year ended December 31, 2018 : Exelon Shares Weighted Average Grant Date Fair Value (per share) Nonvested at December 31, 2017 (a) 2,956,966 $ 32.65 Granted 1,637,542 38.15 Change in performance 1,348,029 30.66 Vested (848,574 ) 36.26 Forfeited (50,467 ) 36.24 Undistributed vested awards (b) (1,640,268 ) 33.38 Nonvested at December 31, 2018 (a) 3,403,228 $ 33.13 __________ (a) Excludes 3,586,259 and 2,723,440 of performance share awards issued to retirement-eligible employees as of December 31, 2018 and 2017 , respectively, as they are fully vested. (b) Represents performance share awards that vested but were not distributed to retirement-eligible employees during 2018 . The following table summarizes the weighted average grant date fair value and the fair value of performance share awards granted and settled for the years ended December 31, 2018 , 2017 and 2016 : Year Ended 2018 (a) 2017 2016 Weighted average grant date fair value (per share) $ 38.15 $ 35.00 $ 28.85 Fair value of performance shares settled 61 72 45 Fair value of performance shares settled in cash 49 56 28 __________ (a) As of December 31, 2018 , $33 million of total unrecognized compensation costs related to nonvested performance shares are expected to be recognized over the remaining weighted-average period of 1.7 years. |
Not Settled Performance Share Awards Balance Sheet Presentation | The following table presents the balance sheet classification of obligations related to outstanding performance share awards not yet settled: December 31, 2018 2017 Current liabilities (a) $ 135 $ 57 Deferred credits and other liabilities (b) 109 100 Common stock 26 26 Total $ 270 $ 183 __________ (a) Represents the current liability related to performance share awards expected to be settled in cash. (b) Represents the long-term liability related to performance share awards expected to be settled in cash. |
Earnings Per Share (Tables)
Earnings Per Share (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Earnings Per Share [Abstract] | |
Reconciliation of basic and diluted earnings per share | The following table sets forth the components of basic and diluted earnings per share and shows the effect of these stock options, performance share awards and restricted stock awards on the weighted average number of shares outstanding used in calculating diluted earnings per share: Year Ended December 31, 2018 2017 2016 Net income attributable to common shareholders $ 2,010 $ 3,786 $ 1,121 Weighted average common shares outstanding — basic 967 947 924 Assumed exercise and/or distributions of stock-based awards 2 2 3 Weighted average common shares outstanding — diluted 969 949 927 |
Changes in Accumulated Other _2
Changes in Accumulated Other Comprehensive Income (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Changes in Accumulated Other Comprehensive Income [Abstract] | |
Schedule Of Accumulated Other Comprehensive Income (Loss) | The following tables present changes in accumulated other comprehensive income (loss) (AOCI) by component for the years ended December 31, 2018 and 2017 : For the Year Ended December 31, 2018 Gains and Unrealized Pension and Foreign AOCI of Investments Total Exelon (a) Beginning balance $ (14 ) $ 10 $ (2,998 ) $ (23 ) $ (1 ) $ (3,026 ) OCI before reclassifications 11 — (143 ) (10 ) 1 (141 ) Amounts reclassified from AOCI (b) 1 — 181 — — 182 Net current-period OCI 12 — 38 (10 ) 1 41 Impact of adoption of Recognition and Measurement of Financial Assets and Financial Liabilities standard (c) — (10 ) — — — (10 ) Ending balance $ (2 ) $ — $ (2,960 ) $ (33 ) $ — $ (2,995 ) Generation (a) Beginning balance $ (16 ) $ 3 $ — $ (23 ) $ (1 ) $ (37 ) OCI before reclassifications 11 — — (10 ) — 1 Amounts reclassified from AOCI (b) 1 — — — — 1 Net current-period OCI 12 — — (10 ) — 2 Impact of adoption of Recognition and Measurement of Financial Assets and Financial Liabilities standard (c) — (3 ) — — — (3 ) Ending balance $ (4 ) $ — $ — $ (33 ) $ (1 ) $ (38 ) PECO (a) Beginning balance $ — $ 1 $ — $ — $ — $ 1 OCI before reclassifications — — — — — — Amounts reclassified from AOCI (b) — — — — — — Net current-period OCI — — — — — — Impact of adoption of Recognition and Measurement of Financial Assets and Financial Liabilities standard (c) — (1 ) — — — (1 ) Ending balance $ — $ — $ — $ — $ — $ — For the Year Ended December 31, 2017 Gains and Unrealized Pension and Foreign AOCI of Investments Total Exelon (a) Beginning balance $ (17 ) $ 4 $ (2,610 ) $ (30 ) $ (7 ) $ (2,660 ) OCI before reclassifications (1 ) 6 11 7 6 29 Amounts reclassified from AOCI (b) 4 — 140 — — 144 Net current-period OCI 3 6 151 7 6 173 Impact of adoption of Reclassification of Certain Tax Effects from AOCI (d) — — (539 ) — — (539 ) Ending balance $ (14 ) $ 10 $ (2,998 ) $ (23 ) $ (1 ) $ (3,026 ) Generation (a) Beginning balance $ (19 ) $ 2 $ — $ (30 ) $ (7 ) $ (54 ) OCI before reclassifications (1 ) 1 — 7 6 13 Amounts reclassified from AOCI (b) 4 — — — — 4 Net current-period OCI 3 1 — 7 6 17 Ending balance $ (16 ) $ 3 $ — $ (23 ) $ (1 ) $ (37 ) PECO (a) Beginning balance $ — $ 1 $ — $ — $ — $ 1 OCI before reclassifications — — — — — — Amounts reclassified from AOCI (b) — — — — — — Net current-period OCI — — — — — — Ending balance $ — $ 1 $ — $ — $ — $ 1 __________ (a) All amounts are net of tax and noncontrolling interests. Amounts in parenthesis represent a decrease in AOCI. (b) See next tables for details about these reclassifications. (c) Exelon prospectively adopted the new standard Recognition and Measurement of Financial Assets and Financial Liabilities. The standard was adopted as of January 1, 2018, which resulted in an increase to Retained earnings and Accumulated other comprehensive loss of $10 million , $3 million and $1 million for Exelon, Generation and PECO, respectively. The amounts reclassified related to Rabbi Trusts. See Note 1 — Significant Accounting Policies for additional information. (d) Exelon early adopted the new standard Reclassification of Certain Tax Effects from AOCI. The standard was adopted retrospectively as of December 31, 2017, which resulted in an increase to Exelon’s Retained earnings and Accumulated other comprehensive loss of $539 million , primarily related to deferred income taxes associated with Exelon’s pension and OPEB obligations. See Note 1 — Significant Accounting Policies for additional information. |
Reclassification Out Of Accumulated Other Comprehensive Income | The following tables present amounts reclassified out of AOCI to Net income for Exelon and Generation during the years ended December 31, 2018 and 2017 : For the Year Ended December 31, 2018 Details about AOCI components Items reclassified out of AOCI (a) Affected line item in the Statement of Operations and Comprehensive Income Exelon Generation Gains (Losses) on cash flow hedges Other cash flow hedges $ (1 ) $ (1 ) Interest expense (1 ) (1 ) Total before tax — — Tax benefit $ (1 ) $ (1 ) Net of tax Amortization of pension and other postretirement benefit plan items Prior service costs (b) $ 90 $ — Actuarial losses (b) (333 ) — (243 ) — Total before tax 62 — Tax benefit $ (181 ) $ — Net of tax Total Reclassifications $ (182 ) $ (1 ) Net of tax For the Year Ended December 31, 2017 Details about AOCI components Items reclassified out of AOCI (a) Affected line item in the Statement of Operations and Comprehensive Income Exelon Generation Gains (Losses) on cash flow hedges Other cash flow hedges $ (5 ) $ (5 ) Interest expense (5 ) (5 ) Total before tax 1 1 Tax benefit $ (4 ) $ (4 ) Net of tax Amortization of pension and other postretirement benefit plan items Prior service costs (b) $ 92 $ — Actuarial losses (b) (324 ) — (232 ) — Total before tax 92 — Tax benefit $ (140 ) $ — Net of tax Total Reclassifications $ (144 ) $ (4 ) Net of tax __________ (a) Amounts in parenthesis represent a decrease in net income. (b) This AOCI component is included in the computation of net periodic pension and OPEB cost. See Note 16 — Retirement Benefits for additional information. |
Schedule of Other Comprehensive Income Loss Tax | The following table presents income tax benefit (expense) allocated to each component of other comprehensive income (loss) during the years ended December 31, 2018 , 2017 and 2016 : For the Year Ended December 31, 2018 2017 2016 Exelon Pension and non-pension postretirement benefit plans: Prior service benefit reclassified to periodic benefit cost $ 24 $ 36 $ 30 Actuarial loss reclassified to periodic benefit cost (86 ) (128 ) (118 ) Pension and non-pension postretirement benefit plans valuation adjustment 50 13 115 Change in unrealized gains on cash flow hedges (5 ) (7 ) — Change in unrealized gains (losses) on investments in unconsolidated affiliates — (3 ) 3 Change in unrealized gains on marketable securities — (1 ) — Total $ (17 ) $ (90 ) $ 30 Generation Change in unrealized gains on cash flow hedges $ (4 ) $ (6 ) $ (2 ) Change in unrealized gains (losses) on investments in unconsolidated affiliates (1 ) (3 ) 3 Change in unrealized gains on marketable securities — (1 ) — Total $ (5 ) $ (10 ) $ 1 |
Commitments and Contingencies_2
Commitments and Contingencies (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Commitments and Contingencies [Line Items] | |
Other Commitments | Commercial Commitments (All Registrants). Exelon’s commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 1,703 $ 1,394 $ 308 $ 1 $ — $ — $ — Surety bonds (a) 1,402 1,331 33 38 — — — Financing trust guarantees 378 — — — — — 378 Guaranteed lease residual values (b) 24 3 3 2 3 3 10 Total commercial commitments $ 3,507 $ 2,728 $ 344 $ 41 $ 3 $ 3 $ 388 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. (b) Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $61 million , $19 million of which is a guarantee by Pepco, $26 million by DPL and $16 million by ACE. The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and PHI believes the likelihood of payments being required under the guarantees is remote. Generation’s commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 1,680 $ 1,380 $ 299 $ 1 $ — $ — $ — Surety bonds (a) 1,220 1,201 19 — — — — Total commercial commitments $ 2,900 $ 2,581 $ 318 $ 1 $ — $ — $ — __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. ComEd’s commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 2 $ 2 $ — $ — $ — $ — $ — Surety bonds (a) 12 10 — 2 — — — Financing trust guarantees 200 — — — — — 200 Total commercial commitments $ 214 $ 12 $ — $ 2 $ — $ — $ 200 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. PECO’s commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Surety bonds (a) $ 9 $ 9 $ — $ — $ — $ — $ — Financing trust guarantees 178 — — — — — 178 Total commercial commitments $ 187 $ 9 $ — $ — $ — $ — $ 178 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. BGE’s commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 3 $ 2 $ 1 $ — $ — $ — $ — Surety bonds (a) 17 3 14 — — — — Total commercial commitments $ 20 $ 5 $ 15 $ — $ — $ — $ — __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. PHI commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 8 $ — $ 8 $ — $ — $ — $ — Surety bonds (a) $ 41 $ 41 $ — $ — $ — $ — $ — Guaranteed lease residual values (b) 24 3 3 2 3 3 10 Total commercial commitments $ 73 $ 44 $ 11 $ 2 $ 3 $ 3 $ 10 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. (b) Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $61 million . The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and PHI believes the likelihood of payments being required under the guarantees is remote. Pepco commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Letters of credit $ 8 $ — $ 8 $ — $ — $ — $ — Surety bonds (a) $ 33 $ 33 $ — $ — $ — $ — $ — Guaranteed lease residual values (b) 8 1 1 1 1 1 3 Total commercial commitments $ 49 $ 34 $ 9 $ 1 $ 1 $ 1 $ 3 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. (b) Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $19 million . The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and Pepco believes the likelihood of payments being required under the guarantees is remote. DPL commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Surety bonds (a) $ 5 $ 5 $ — $ — $ — $ — $ — Guaranteed lease residual values (b) 10 1 1 1 1 1 5 Total commercial commitments $ 15 $ 6 $ 1 $ 1 $ 1 $ 1 $ 5 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. (b) Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $26 million . The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and DPL believes the likelihood of payments being required under the guarantees is remote. ACE commercial commitments as of December 31, 2018 , representing commitments potentially triggered by future events, were as follows: Expiration within Total 2019 2020 2021 2022 2023 2024 and beyond Surety bonds (a) $ 3 $ 3 $ — $ — $ — $ — $ — Guaranteed lease residual values (b) 6 1 1 — 1 1 2 Total commercial commitments $ 9 $ 4 $ 1 $ — $ 1 $ 1 $ 2 __________ (a) Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. (b) Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $16 million . The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and ACE believes the likelihood of payments being required under the guarantees is remot |
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block] | mum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $16 million . The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and ACE believes the likelihood of payments being required under the guarantees is remote. Leases (All Registrants) Minimum future operating lease payments, including lease payments for contracted generation, vehicles, real estate, computers, rail cars, operating equipment and office equipment, as of December 31, 2018 were: Exelon (a)(b) Generation (a)(b) ComEd (a)(c) PECO (a)(c) BGE (a)(c)(d)(e) PHI (a) Pepco (a) DPL (a)(c) ACE (a) 2019 $ 140 $ 33 $ 7 $ 5 $ 35 $ 48 $ 11 $ 14 $ 7 2020 149 46 5 5 35 46 10 13 6 2021 143 46 4 5 33 43 9 12 5 2022 126 47 4 5 18 42 8 12 5 2023 97 46 3 5 3 39 8 10 4 Remaining years 723 545 — — 19 159 40 35 5 Total minimum future lease payments $ 1,378 $ 763 $ 23 $ 25 $ 143 $ 377 $ 86 $ 96 $ 32 __________ (a) Includes amounts related to shared use land arrangements. (b) Excludes Generation’s contingent operating lease payments associated with contracted generation agreements. (c) Amounts related to certain real estate leases and railroad licenses effectively have indefinite payment periods. As a result, ComEd, PECO, BGE and DPL have excluded these payments from the remaining years as such amounts would not be meaningful. ComEd's, PECO’s, BGE’s and DPL's average annual obligation for these arrangements, included in each of the years 2019 - 2023 , was $3 million , $5 million , $1 million and $1 million respectively. Also includes amounts related to shared use land arrangements. (d) Includes all future lease payments on a 99 -year real estate lease that expires in 2106 . (e) The BGE column above includes minimum future lease payments associated with a 6-year lease for the Baltimore City conduit system that became effective during the fourth quarter of 2016. BGE's total commitments under the lease agreement are $26 million , $28 million , $28 million and $14 million related to years 2019 - 2022 |
Accrued environmental liabilities | . As of December 31, 2018 and 2017 , the Registrants had accrued the following undiscounted amounts for environmental liabilities in Other current liabilities and Other deferred credits and other liabilities within their respective Consolidated Balance Sheets: December 31, 2018 Total environmental investigation and remediation reserve Portion of total related to MGP investigation and remediation Exelon $ 496 $ 356 Generation 108 — ComEd 329 327 PECO 27 25 BGE 5 4 PHI 27 — Pepco 25 — DPL 1 — ACE 1 — |
Schedule of Government Settlement Agreements [Table Text Block] | . Under the settlement agreements, Generation has received cumulative cash reimbursements for costs incurred as follows: Total Net (a) Cumulative cash reimbursements (b) $ 1,274 $ 1,100 __________ (a) Total after considering amounts due to co-owners of certain nuclear stations and to the former owner of Oyster Creek. (b) Includes $53 and $49 , respectively, for amounts received since April 1, 2014, for costs incurred under the CENG DOE Settlement Agreements prior to the consolidation of CENG. As of December 31, 2018 and 2017 , the amount of SNF storage costs for which reimbursement has been or will be requested from the DOE under the DOE settlement agreements is as follows: December 31, 2018 December 31, 2017 DOE receivable - current (a) $ 124 $ 94 DOE receivable - noncurrent (b) 15 15 Amounts owed to co-owners (a)(c) (17 ) (11 ) __________ (a) Recorded in Accounts receivable, other. (b) Recorded in Deferred debits and other assets, other (c) Non-CENG amounts owed to co-owners are recorded in Accounts receivable, other. CENG amounts owed to co-owners are recorded in Accounts payable. Represents amounts owed to the co-owners of Peach Bottom, Quad Cities, and Nine Mile Point Unit 2 generating facilities |
Supplemental Financial Inform_2
Supplemental Financial Information (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Supplemental Financial Information [Abstract] | |
Schedule Of Taxes Excluding Income And Excise Taxes [Table Text Block] | The following tables provide additional information about the Registrants’ Consolidated Statements of Operations and Comprehensive Income for the years ended December 31, 2018 , 2017 and 2016 . For the year ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Taxes other than income Utility (a) $ 919 $ 114 $ 243 $ 131 $ 94 $ 337 $ 316 $ 21 $ — Property 557 273 30 15 143 94 58 32 3 Payroll 247 130 27 16 17 24 5 3 2 Other 60 39 11 1 — — — — — Total taxes other than income $ 1,783 $ 556 $ 311 $ 163 $ 254 $ 455 $ 379 $ 56 $ 5 For the year ended December 31, 2017 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Taxes other than income Utility (a) $ 898 $ 126 $ 240 $ 125 $ 89 $ 318 $ 300 $ 18 $ — Property 545 269 28 14 132 101 62 32 3 Payroll 230 121 26 15 15 26 6 4 2 Other 58 39 2 — 4 7 3 3 1 Total taxes other than income $ 1,731 $ 555 $ 296 $ 154 $ 240 $ 452 $ 371 $ 57 $ 6 Successor Predecessor For the year ended December 31, 2016 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Taxes other than income Utility (a) $ 753 $ 122 $ 242 $ 136 $ 85 $ 312 $ 18 $ — $ 253 $ 78 Property 483 246 27 13 123 53 31 3 73 18 Payroll 226 117 28 15 17 8 5 3 23 8 Other 114 21 (4 ) — 4 4 1 1 5 1 Total taxes other than income $ 1,576 $ 506 $ 293 $ 164 $ 229 $ 377 $ 55 $ 7 $ 354 $ 105 __________ (a) Generation’s utility tax represents gross receipts tax related to its retail operations and ComEd’s, PECO’s, BGE’s, Pepco's, DPL's and ACE's utility taxes represent municipal and state utility taxes and gross receipts taxes related to their operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. |
Schedule of Other Nonoperating Income, by Component [Table Text Block] | For the year ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Other, Net Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 506 $ 506 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 302 302 — — — — — — — Net unrealized losses on NDT funds Regulatory agreement units (715 ) (715 ) — — — — — — — Non-regulatory agreement units (483 ) (483 ) — — — — — — — Net unrealized losses on pledged assets Zion Station decommissioning (8 ) (8 ) — — — — — — — Regulatory offset to NDT fund-related activities (b) 171 171 — — — — — — — Total decommissioning-related activities (227 ) (227 ) — — — — — — — Investment income 43 32 — 1 1 4 2 1 — Interest income related to uncertain income tax positions 5 1 — — — — — — — AFUDC—Equity 69 — 19 7 18 25 22 2 1 Non-service net periodic benefit cost (47 ) — — — — — — — — Other 45 16 14 — — 14 7 7 1 Other, net $ (112 ) $ (178 ) $ 33 $ 8 $ 19 $ 43 $ 31 $ 10 $ 2 For the year ended December 31, 2017 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Other, Net Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 488 $ 488 $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 209 209 — — — — — — — Net unrealized gains on NDT funds Regulatory agreement units 455 455 — — — — — — — Non-regulatory agreement units 521 521 — — — — — — — Net unrealized losses on pledged assets Zion Station decommissioning (10 ) (10 ) — — — — — — — Regulatory offset to NDT fund-related activities (b) (724 ) (724 ) — — — — — — — Total decommissioning-related activities 939 939 — — — — — — — Investment income 8 6 — — — 2 1 — — Interest income (expense) related to uncertain income tax positions 3 (1 ) — — — — — — — Benefit related to uncertain income tax positions (c) 2 — — — — — — — — AFUDC—Equity 73 — 12 9 16 36 23 7 6 Non-service net periodic benefit cost (109 ) — — — — — — — — Other 31 4 10 — — 16 8 7 1 Other, net $ 947 $ 948 $ 22 $ 9 $ 16 $ 54 $ 32 $ 14 $ 7 Successor Predecessor For the year ended December 31, 2016 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Other, Net Decommissioning-related activities: Net realized income on NDT funds (a) Regulatory agreement units $ 237 $ 237 $ — $ — $ — $ — $ — $ — $ — $ — Non-regulatory agreement units 126 126 — — — — — — — — Net unrealized gains on NDT funds Regulatory agreement units 216 216 — — — — — — — — Non-regulatory agreement units 194 194 — — — — — — — — Net unrealized losses on pledged assets Zion Station decommissioning (1 ) (1 ) — — — — — — — — Regulatory offset to NDT fund-related activities (b) (372 ) (372 ) — — — — — — — — Total decommissioning-related activities 400 400 — — — — — — — — Investment income (loss) 17 8 — (1 ) 2 1 — 1 1 — Long-term lease income 4 — — — — — — — — — Interest income (expense) related to uncertain income tax positions 13 — — — — 1 — — (1 ) — Penalty related to uncertain income tax positions (c) (106 ) — (86 ) — — — — — — — AFUDC—Equity 64 — 14 8 19 19 5 6 23 7 Non-service net periodic benefit cost (116 ) — — — — — — — — — Loss on debt extinguishment (3 ) (2 ) — — — — — — — — Other 24 (5 ) 7 1 — 15 8 2 21 (11 ) Other, net $ 297 $ 401 $ (65 ) $ 8 $ 21 $ 36 $ 13 $ 9 $ 44 $ (4 ) __________ (a) Includes investment income and realized gains and losses on sales of investments within the NDT funds. (b) Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of net income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning. (c) See Note 14 — Income Taxes for additional information on the penalty related to the Tax Court’s decision on Exelon’s like-kind exchange tax position. |
Cash Flow Supplemental Disclosures | The following tables provide additional information regarding the Registrants’ Consolidated Statements of Cash Flows for the years ended December 31, 2018 , 2017 and 2016 . For the year ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Depreciation, amortization and accretion Property, plant and equipment $ 3,740 $ 1,748 $ 820 $ 274 $ 335 $ 480 $ 218 $ 131 $ 94 Regulatory assets 555 — 120 27 148 260 167 51 42 Amortization of intangible assets, net 58 49 — — — — — — — Amortization of energy contract assets and liabilities (a) 14 14 — — — — — — — Nuclear fuel (b) 1,115 1,115 — — — — — — — ARO accretion (c) 489 489 — — — — — — — Total depreciation, amortization and accretion $ 5,971 $ 3,415 $ 940 $ 301 $ 483 $ 740 $ 385 $ 182 $ 136 For the year ended December 31, 2017 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Depreciation, amortization and accretion Property, plant and equipment $ 3,293 $ 1,409 $ 777 $ 261 $ 312 $ 457 $ 203 $ 124 $ 89 Regulatory assets 478 — 73 25 161 218 118 43 57 Amortization of intangible assets, net 57 48 — — — — — — — Amortization of energy contract assets and liabilities (a) 35 35 — — — — — — — Nuclear fuel (b) 1,096 1,096 — — — — — — — ARO accretion (c) 468 468 — — — — — — — Total depreciation, amortization and accretion $ 5,427 $ 3,056 $ 850 $ 286 $ 473 $ 675 $ 321 $ 167 $ 146 Successor Predecessor For the year ended December 31, 2016 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Depreciation, amortization and accretion Property, plant and equipment $ 3,477 $ 1,835 $ 708 $ 244 $ 299 $ 175 $ 110 $ 82 $ 325 $ 94 Regulatory assets 407 — 67 26 124 120 47 83 190 58 Amortization of intangible assets, net 52 44 — — — — — — — — Amortization of energy contract assets and liabilities (a) 35 35 — — — — — — — — Nuclear fuel (b) 1,159 1,159 — — — — — — — — ARO accretion (c) 446 446 — — — — — — — — Total depreciation, amortization and accretion $ 5,576 $ 3,519 $ 775 $ 270 $ 423 $ 295 $ 157 $ 165 $ 515 $ 152 __________ (a) Included in Operating revenues or Purchased power and fuel in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. (b) Included in Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. (c) Included in Operating and maintenance expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. For the year ended December 31, 2018 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Cash paid (refunded) during the year: Interest (net of amount capitalized) $ 1,421 $ 369 $ 332 $ 125 $ 94 $ 250 $ 123 $ 56 $ 61 Income taxes (net of refunds) 95 746 (153 ) (2 ) 14 (32 ) 41 (6 ) (12 ) Other non-cash operating activities: Pension and non-pension postretirement benefit costs $ 583 $ 204 $ 177 $ 18 $ 59 $ 67 $ 15 $ 6 $ 12 Loss (gain) from equity method investments 28 30 — — — (1 ) — — — Provision for uncollectible accounts 159 48 40 33 10 28 11 6 11 Provision for excess and obsolete inventory 24 20 3 — — — — — — Stock-based compensation costs 75 — — — — — — — — Other decommissioning-related activity (a) (2 ) (2 ) — — — — — — — Energy-related options (b) 10 10 — — — — — — — Amortization of regulatory asset related to debt costs 8 — 3 1 — 4 2 1 1 Amortization of rate stabilization deferral 14 — — — — 14 14 — — Amortization of debt fair value adjustment (15 ) (12 ) — — — (3 ) — — — Merger-related commitments (c) — — — — — 5 — 5 — Severance costs 35 9 — — — — — — — Asset retirement costs 20 — — — — 20 22 (1 ) (1 ) Amortization of debt costs 36 14 5 2 1 3 2 — 1 Discrete impacts from EIMA and FEJA (d) 28 — 28 — — — — — — Long-term incentive plan 140 — — — — — — — — Other (19 ) (23 ) (14 ) (3 ) (12 ) 6 (6 ) 7 — Total other non-cash operating activities $ 1,124 $ 298 $ 242 $ 51 $ 58 $ 143 $ 60 $ 24 $ 24 Non-cash investing and financing activities: Change in capital expenditures not paid $ (69 ) $ (199 ) $ 11 $ (12 ) $ 50 $ 93 $ 20 $ 22 $ 46 Change in PPE related to ARO update (107 ) (130 ) 7 — 1 15 12 2 1 Dividends on stock compensation 6 — — — — — — — — Acquisition of land 3 — — — — 3 — — 3 __________ (a) Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning. (b) Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations. (c) See Note 5 - Mergers, Acquisitions and Dispositions for additional information. (d) Reflects the change in ComEd's distribution and energy efficiency formula rates. See Note 4 — Regulatory Matters for additional information. For the year ended December 31, 2017 Successor Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Cash paid (refunded) during the year: Interest (net of amount capitalized) $ 2,430 $ 391 $ 307 $ 103 $ 96 $ 236 $ 114 $ 49 $ 59 Income taxes (net of refunds) 540 337 83 47 (2 ) (144 ) (104 ) (49 ) (2 ) Other non-cash operating activities: Pension and non-pension postretirement benefit costs $ 643 $ 227 $ 176 $ 29 $ 62 $ 94 $ 25 $ 13 $ 13 Loss (gain) from equity method investments 32 33 — — — (1 ) — — — Provision for uncollectible accounts 125 38 34 26 8 19 8 3 8 Provision for excess and obsolete inventory 56 51 3 — — 2 1 1 — Stock-based compensation costs 88 — — — — — — — — Other decommissioning-related activity (a) (313 ) (313 ) — — — — — — — Energy-related options (b) 7 7 — — — — — — — Amortization of regulatory asset related to debt costs 9 — 4 1 — 4 2 1 1 Amortization of rate stabilization deferral (10 ) — — — 7 (17 ) (17 ) — — Amortization of debt fair value adjustment (18 ) (12 ) — — — (6 ) — — — Merger-related commitments (c) — — — — — (8 ) (6 ) (2 ) — Severance costs 35 31 — — — 3 — — — Amortization of debt costs 64 37 5 2 2 4 2 — 1 Discrete impacts from EIMA and FEJA (d) (52 ) — (52 ) — — — — — — Vacation accrual adjustment (e) (68 ) (35 ) (12 ) — — (8 ) (8 ) — — Long-term incentive plan 109 — — — — — — — — Change in environmental liabilities 44 44 — — — — — — — Other (30 ) 4 6 (4 ) (14 ) (28 ) (13 ) (7 ) (6 ) Total other non-cash operating activities $ 721 $ 112 $ 164 $ 54 $ 65 $ 58 $ (6 ) $ 9 $ 17 Non-cash investing and financing activities: Change in capital expenditures not paid $ 42 $ 73 $ (61 ) $ 22 $ 23 $ (12 ) $ 5 $ 4 $ (13 ) Change in PPE related to ARO update 29 29 — — — — — — — Non-cash financing of capital projects 16 16 — — — — — — — Indemnification of like-kind exchange position (f) — — 21 — — — — — — Dividends on stock compensation 7 — — — — — — — — Dissolution of financing trust due to long-term debt retirement 8 — — — 8 — — — — Fair value adjustment of long-term debt due to retirement (5 ) — — — — — — — — Fair value of pension and OPEB obligation transferred in connection with FitzPatrick — 33 — — — — — — — __________ (a) Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning. (b) Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations. (c) See Note 5 - Mergers, Acquisitions and Dispositions for additional information. (d) Reflects the change in ComEd's distribution and energy efficiency formula rates . See Note 4 — Regulatory Matters for additional information. (e) On December 1, 2017, Exelon adopted a single, standard vacation accrual policy for all non-represented, non-craft (represented and craft policies remained unchanged) employees effective January 1, 2018. To reflect the new policy, Exelon recorded a one-time, $68 million pre-tax credit to expense to reverse 2018 vacation cost originally accrued throughout 2017 that will now be accrued ratably over the year in 2018. (f) See Note 14 — Income Taxes for additional information on the like-kind exchange tax position. Successor Predecessor For the year ended December 31, 2016 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Cash paid (refunded) during the year: Interest (net of amount capitalized) $ 1,340 $ 339 $ 298 $ 104 $ 92 $ 118 $ 47 $ 62 $ 209 $ 43 Income taxes (net of refunds) (441 ) 435 (444 ) 64 31 216 115 200 258 11 Other non-cash operating activities: Pension and non-pension postretirement benefit costs $ 619 $ 218 $ 166 $ 33 $ 67 $ 31 $ 18 $ 15 $ 86 $ 23 Loss from equity method investments 24 25 — — — — — — — — Provision for uncollectible accounts 155 19 41 30 1 29 23 32 65 16 Stock-based compensation costs 111 — — — — — — — — 3 Other decommissioning-related activity (a) (384 ) (384 ) — — — — — — — — Energy-related options (b) (11 ) (11 ) — — — — — — — — Amortization of regulatory asset related to debt costs 9 — 4 1 — 2 1 1 3 1 Amortization of rate stabilization deferral 76 — — — 81 (12 ) 2 — (5 ) 5 Amortization of debt fair value adjustment (11 ) (11 ) — — — — — — — — Merger-related commitments (c)(d) 558 53 — — — 125 82 110 317 — Severance costs 99 22 — — — — — — 56 — Discrete impacts from EIMA (e) 8 — 8 — — — — — — — Amortization of debt costs 35 17 4 3 1 — — — 1 — Provision for excess and obsolete inventory 12 6 4 — — 3 1 1 1 1 Lower of cost or market inventory adjustment 37 36 — 1 — — — — — — Baltimore City Conduit Lease Settlement (28 ) — — — (28 ) — — — — — Cash Working Capital Order (13 ) — — — (13 ) — — — — — Asset retirement costs 2 — — — — — 1 2 2 — Long-term incentive plan 70 — — — — — — — — — Other (35 ) 25 (12 ) (3 ) (21 ) (3 ) (14 ) (6 ) (11 ) (3 ) Total other non-cash operating activities $ 1,333 $ 15 $ 215 $ 65 $ 88 $ 175 $ 114 $ 155 $ 515 $ 46 Non-cash investing and financing activities: Change in capital expenditures not paid $ (128 ) $ 50 $ (91 ) $ (11 ) $ (86 ) $ 27 $ (12 ) $ 11 $ 21 $ 11 Change in PPE related to ARO update 191 191 — — — — — — — — Indemnification of like-kind exchange position (g) — — 158 — — — — — — — Dividends on stock compensation 6 — — — — — — — — — Non-cash financing of capital projects 95 95 — — — — — — — — Sale of Upstream assets (c) 37 37 — — — — — — — — Pending FitzPatrick Acquisition (h) (54 ) (54 ) — — — — — — — — Fair value of net assets contributed to Generation in connection with the PHI merger, net of cash — 119 — — — — — — — — Fair value of net assets distributed to Exelon in connection with the PHI Merger, net of cash (c)(f) — — — — — — — — 127 — Fair value of pension obligation transferred in connection with the PHI Merger, net of cash (c)(f) — — — — — — — — 53 — Assumption of member purchase liability — — — — — — — — 29 — Assumption of merger commitment liability — — — — — 33 — — 33 — __________ (a) Includes the elimination of NDT fund activity for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning. (b) Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations. (c) See Note 5 - Mergers, Acquisitions and Dispositions for additional information. (d) Excludes $5 million of forgiveness of Accounts receivable related to merger commitments recorded in connection with the PHI Merger, the balance is included within Provision for uncollectible accounts. (e) Reflects the change in distribution rates pursuant to EIMA, which allows for the recovery of costs by a utility through a pre-established performance-based formula rate. See Note 4 — Regulatory Matters for additional information. (f) Immediately following closing of the PHI Merger, the net assets associated with PHI’s unregulated business interests were distributed by PHI to Exelon. Exelon contributed a portion of such net assets to Generation. (g) See Note 14 — Income Taxes for additional information on the like-kind exchange tax position. (h) Reflects the transfer of nuclear fuel to Entergy under the cost reimbursement provisions of the FitzPatrick acquisition agreements. See Note 5 - Mergers, Acquisitions and Dispositions for additional information. The following tables provide a reconciliation of cash, cash equivalents and restricted cash reported within the Registrants' Consolidated Balance Sheets that sum to the total of the same amounts in their Consolidated Statements of Cash Flows. Successor December 31, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Cash and cash equivalents $ 1,349 $ 750 $ 135 $ 130 $ 7 $ 124 $ 16 $ 23 $ 7 Restricted cash 247 153 29 5 6 43 37 1 4 Restricted cash included in other long-term assets 185 — 166 — — 19 — — 19 Total cash, cash equivalents and restricted cash $ 1,781 $ 903 $ 330 $ 135 $ 13 $ 186 $ 53 $ 24 $ 30 Successor December 31, 2017 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Cash and cash equivalents $ 898 $ 416 $ 76 $ 271 $ 17 $ 30 $ 5 $ 2 $ 2 Restricted cash 207 138 5 4 1 42 35 — 6 Restricted cash included in other long-term assets 85 — 63 — — 23 — — 23 Total cash, cash equivalents and restricted cash $ 1,190 $ 554 $ 144 $ 275 $ 18 $ 95 $ 40 $ 2 $ 31 Successor Predecessor December 31, 2016 December 31, 2016 March 23, 2016 Exelon Generation ComEd PECO BGE Pepco DPL ACE PHI PHI Cash and cash equivalents $ 635 $ 290 $ 56 $ 63 $ 23 $ 9 $ 46 $ 101 $ 170 $ 319 Restricted cash 253 158 2 4 24 33 — 9 43 11 Restricted cash included in other long-term assets 26 — — — 3 — — 23 23 18 Total cash, cash equivalents and restricted cash $ 914 $ 448 $ 58 $ 67 $ 50 $ 42 $ 46 $ 133 $ 236 $ 348 Predecessor December 31, 2015 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Cash and cash equivalents $ 6,502 $ 431 $ 67 $ 295 $ 9 $ 26 $ 5 $ 5 $ 3 Restricted cash 205 123 2 3 24 14 2 — 12 Restricted cash included in other long-term assets 5 2 — — 3 18 — — 18 Total cash, cash equivalents and restricted cash $ 6,712 $ 556 $ 69 $ 298 $ 36 $ 58 $ 7 $ 5 $ 33 |
Supplemental Balance Sheet Disclosures [Text Block] | The following tables provide additional information about assets and liabilities of the Registrants at December 31, 2018 and 2017 . December 31, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Unbilled customer revenues (a) $ 1,656 $ 965 $ 223 $ 114 $ 168 $ 186 $ 97 $ 59 $ 30 Allowance for uncollectible accounts (b) (319 ) (104 ) (81 ) (61 ) (20 ) (53 ) (21 ) (13 ) (19 ) December 31, 2017 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Unbilled customer revenues (a) $ 1,858 $ 1,017 $ 242 $ 162 $ 205 $ 232 $ 133 $ 68 $ 31 Allowance for uncollectible (b) (322 ) (114 ) (73 ) (56 ) (24 ) (55 ) (21 ) (16 ) (18 ) __________ (a) Represents unbilled portion of receivables estimated under Exelon’s unbilled critical accounting policy. (b) Includes the estimated allowance for uncollectible accounts on billed customer and other accounts receivable. The Utility Registrants are required, under separate legislation and regulations in Illinois, Pennsylvania, Maryland, District of Columbia and New Jersey, to purchase certain receivables from alternative retail electric and, as applicable, natural gas suppliers that participate in the utilities' consolidated billing. ComEd, BGE, Pepco and DPL purchase receivables at a discount to recover primarily uncollectible accounts expense from the suppliers. PECO and ACE purchase receivables at face value and recover uncollectible accounts expense, including those from alternative retail electric and natural gas supplies, through base distribution rates and a rate rider, respectively. Exelon and the Utility Registrants do not record unbilled commodity receivables under their POR programs. Purchased billed receivables are recorded on a net basis in Exelon’s and the Utility Registrant's Consolidated Statements of Operations and Comprehensive Income and are classified in Other accounts receivable, net in their Consolidated Balance Sheets. The following tables provide information about the purchased receivables of those companies as of December 31, 2018 and 2017 . December 31, 2018 Exelon ComEd PECO BGE PHI Pepco DPL ACE Purchased receivables $ 313 $ 94 $ 74 $ 61 $ 84 $ 57 $ 8 $ 19 Allowance for uncollectible accounts (a) (34 ) (17 ) (5 ) (3 ) (9 ) (5 ) (1 ) (3 ) Purchased receivables, net $ 279 $ 77 $ 69 $ 58 $ 75 $ 52 $ 7 $ 16 December 31, 2017 Exelon ComEd PECO BGE PHI Pepco DPL ACE Purchased receivables $ 298 $ 87 $ 70 $ 58 $ 83 $ 56 $ 9 $ 18 Allowance for uncollectible accounts (a) (31 ) (14 ) (5 ) (3 ) (9 ) (5 ) (1 ) (3 ) Purchased receivables, net $ 267 $ 73 $ 65 $ 55 $ 74 $ 51 $ 8 $ 15 __________ (a) For ComEd, BGE, Pepco and DPL, reflects the incremental allowance for uncollectible accounts recorded, which is in addition to the purchase discount. For ComEd, the incremental uncollectible accounts expense is recovered through a rate rider. BGE, Pepco and DPL recover actual write-offs which are reflected in the POR discount rate. The following tables provide additional information about Registrants' investments at December 31, 2018 and 2017 . December 31, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Investments Equity method investments: Financing trusts (a) $ 14 $ — $ 6 $ 8 $ — $ — $ — $ — $ — Bloom 180 180 — — — — — — — NET Power 70 70 — — — — — — — Other equity method investments 3 1 — — — — — — — Total equity method investments 267 251 6 8 — — — — — Other investments: Employee benefit trusts and investments (b) 244 49 — 17 5 130 105 — — Equity investments without readily determinable fair values 72 72 — — — — — — — Other available for sale debt security investments 40 40 — — — — — — — Other 2 2 — — — — — — — Total investments $ 625 $ 414 $ 6 $ 25 $ 5 $ 130 $ 105 $ — $ — December 31, 2017 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Investments Equity method investments: Financing trusts (a) $ 14 $ — $ 6 $ 8 $ — $ — $ — $ — $ — Bloom 206 206 — — — — — — — NET Power 76 76 — — — — — — — Other equity method investments 1 1 — — — — — — — Total equity method investments 297 283 6 8 — — — — — Other investments: Employee benefit trusts and investments (b) 244 51 — 17 5 132 102 — — Equity investments without readily determinable fair values 62 62 — — — — — — — Other available for sale debt security investments 37 37 — — — — — — — Total investments $ 640 $ 433 $ 6 $ 25 $ 5 $ 132 $ 102 $ — $ — __________ (a) Includes investments in affiliated financing trusts, which were not consolidated within the financial statements of Exelon and are shown as investments in the Consolidated Balance Sheets. See Note 1 — Significant Accounting Policies for additional information. (b) The Registrants’ debt and equity security investments are recorded at fair market value. The following tables provide additional information about liabilities of the Registrants at December 31, 2018 and 2017 . December 31, 2018 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Accrued expenses Compensation-related accruals (a) $ 1,191 $ 479 $ 187 $ 49 $ 68 $ 99 $ 29 $ 19 $ 12 Taxes accrued 412 226 71 28 46 74 58 4 5 Interest accrued 334 77 105 33 39 50 25 8 12 Severance accrued 44 26 2 — — 5 — — — Other accrued expenses 131 90 8 3 2 28 14 8 6 Total accrued expenses $ 2,112 $ 898 $ 373 $ 113 $ 155 $ 256 $ 126 $ 39 $ 35 December 31, 2017 Exelon Generation ComEd PECO BGE PHI Pepco DPL ACE Accrued expenses Compensation-related accruals (a) $ 978 $ 407 $ 158 $ 64 $ 58 $ 106 $ 29 $ 17 $ 11 Taxes accrued 373 444 60 15 71 61 68 4 5 Interest accrued 328 78 102 33 34 48 23 8 12 Severance accrued 58 30 2 — — 17 — — — Other accrued expenses 100 63 5 2 1 29 17 6 5 Total accrued expenses $ 1,837 $ 1,022 $ 327 $ 114 $ 164 $ 261 $ 137 $ 35 $ 33 __________ (a) Primarily includes accrued payroll, bonuses and other incentives, vacation and benefits. |
Segment Information (Tables)
Segment Information (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Segment Reporting [Abstract] | |
Analysis and reconciliation of reportable segment information | An analysis and reconciliation of the Registrants’ reportable segment information to the respective information in the consolidated financial statements for the years ended December 31, 2018 , 2017 , and 2016 is as follows: Successor Generation (a) ComEd PECO BGE PHI (e) Other (b) Intersegment Exelon Operating revenues (c) : 2018 Competitive businesses electric revenues $ 17,411 $ — $ — $ — $ — $ — $ (1,256 ) $ 16,155 Competitive businesses natural gas revenues 2,718 — — — — — (8 ) 2,710 Competitive businesses other revenues 308 — — — — — (5 ) 303 Rate-regulated electric revenues — 5,882 2,470 2,428 4,609 — (45 ) 15,344 Rate-regulated natural gas revenues — — 568 741 181 — (20 ) 1,470 Shared service and other revenues — — — — 15 1,948 (1,960 ) 3 Total operating revenues $ 20,437 $ 5,882 $ 3,038 $ 3,169 $ 4,805 $ 1,948 $ (3,294 ) $ 35,985 2017 Competitive businesses electric revenues $ 15,332 $ — $ — $ — $ — $ — $ (1,105 ) $ 14,227 Competitive businesses natural gas revenues 2,575 — — — — — — 2,575 Competitive businesses other revenues 593 — — — — — (1 ) 592 Rate-regulated electric revenues — 5,536 2,375 2,489 4,469 — (29 ) 14,840 Rate-regulated natural gas revenues — — 495 687 161 — (10 ) 1,333 Shared service and other revenues — — — — 49 1,831 (1,880 ) — Total operating revenues $ 18,500 $ 5,536 $ 2,870 $ 3,176 $ 4,679 $ 1,831 $ (3,025 ) $ 33,567 Successor Generation (a) ComEd PECO BGE PHI (e) Other (b) Intersegment Exelon 2016 Competitive businesses electric revenues $ 15,400 $ — $ — $ — $ — $ — $ (1,430 ) $ 13,970 Competitive businesses natural gas revenues 2,146 — — — — — — 2,146 Competitive businesses other revenues 211 — — — — — (4 ) 207 Rate-regulated electric revenues — 5,254 2,531 2,609 3,506 — (31 ) 13,869 Rate-regulated natural gas revenues — — 463 624 92 — (13 ) 1,166 Shared service and other revenues — — — — 45 1,648 (1,686 ) 7 Total operating revenues $ 17,757 $ 5,254 $ 2,994 $ 3,233 $ 3,643 $ 1,648 $ (3,164 ) $ 31,365 Intersegment revenues (d) : 2018 $ 1,269 $ 27 $ 8 $ 29 $ 15 $ 1,942 $ (3,289 ) $ 1 2017 1,110 15 7 16 50 1,824 (3,020 ) 2 2016 1,428 15 8 21 45 1,647 (3,159 ) 5 Depreciation and amortization: 2018 $ 1,797 $ 940 $ 301 $ 483 $ 740 $ 92 $ — $ 4,353 2017 1,457 850 286 473 675 87 — 3,828 2016 1,879 775 270 423 515 74 — 3,936 Operating expenses (c) : 2018 $ 19,510 $ 4,741 $ 2,452 $ 2,696 $ 4,156 $ 1,929 $ (3,341 ) $ 32,143 2017 18,001 4,214 2,215 2,562 3,911 1,742 (3,026 ) 29,619 2016 16,878 4,056 2,292 2,683 3,549 1,812 (3,164 ) 28,106 Interest expense, net: 2018 $ 432 $ 347 $ 129 $ 106 $ 261 $ 279 $ — $ 1,554 2017 440 361 126 105 245 283 — 1,560 2016 364 461 123 103 195 290 — 1,536 Income (loss) before income taxes: 2018 $ 365 $ 832 $ 466 $ 387 $ 432 $ (249 ) $ (1 ) $ 2,232 2017 1,455 984 538 525 578 (296 ) (2 ) 3,782 2016 857 679 587 468 (58 ) (555 ) (5 ) 1,973 Income taxes: 2018 $ (108 ) $ 168 $ 6 $ 74 $ 35 $ (55 ) $ — $ 120 2017 (1,376 ) 417 104 218 217 294 — (126 ) 2016 282 301 149 174 3 (156 ) — 753 Successor Generation (a) ComEd PECO BGE PHI (e) Other (b) Intersegment Exelon Net income (loss): 2018 $ 443 $ 664 $ 460 $ 313 $ 398 $ (193 ) $ (1 ) $ 2,084 2017 2,798 567 434 307 362 (590 ) (2 ) 3,876 2016 550 378 438 294 (61 ) (398 ) (5 ) 1,196 Capital expenditures: 2018 $ 2,242 $ 2,126 $ 849 $ 959 $ 1,375 $ 43 $ — $ 7,594 2017 $ 2,259 $ 2,250 $ 732 $ 882 $ 1,396 $ 65 $ — $ 7,584 2016 $ 3,078 $ 2,734 $ 686 $ 934 $ 1,008 $ 113 $ — $ 8,553 Total assets: 2018 $ 47,556 $ 31,213 $ 10,642 $ 9,716 $ 21,984 $ 8,355 $ (9,800 ) $ 119,666 2017 48,457 29,726 10,170 9,104 21,247 8,618 (10,552 ) 116,770 __________ (a) See Note 25 — Related Party Transactions for additional information on intersegment revenues. (b) Other primarily includes Exelon’s corporate operations, shared service entities and other financing and investment activities. (c) Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 23 — Supplemental Financial Information for additional information on total utility taxes. (d) Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory authoritative guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. (e) Amounts included represent activity for PHI's successor period, March 24, 2016 through December 31, 2018 . Successor and Predecessor PHI: Pepco DPL ACE Other (b) Intersegment PHI Operating revenues (a) : December 31, 2018 - Successor Rate-regulated electric revenues $ 2,239 $ 1,151 $ 1,236 $ — $ (17 ) $ 4,609 Rate-regulated natural gas revenues — 181 — — — 181 Shared service and other revenues — — — 435 (420 ) 15 Total operating revenues $ 2,239 $ 1,332 $ 1,236 $ 435 $ (437 ) $ 4,805 December 31, 2017 - Successor Rate-regulated electric revenues $ 2,158 $ 1,139 $ 1,186 $ — $ (14 ) $ 4,469 Rate-regulated natural gas revenues — 161 — — — 161 Shared service and other revenues — — — 52 (3 ) 49 Total operating revenues $ 2,158 $ 1,300 $ 1,186 $ 52 $ (17 ) $ 4,679 March 24, 2016 to December 31, 2016 - Successor Rate-regulated electric revenues $ 1,675 $ 850 $ 989 $ 5 $ (13 ) $ 3,506 Rate-regulated natural gas revenues — 92 — — — 92 Shared service and other revenues — — — 45 — 45 Total operating revenues $ 1,675 $ 942 $ 989 $ 50 $ (13 ) $ 3,643 January 1, 2016 to March 23, 2016 - Predecessor Rate-regulated electric revenues $ 511 $ 279 $ 268 $ 42 $ (4 ) $ 1,096 Rate-regulated natural gas revenues — 56 — 1 — 57 Shared service and other revenues — — — — — — Total operating revenues $ 511 $ 335 $ 268 $ 43 $ (4 ) $ 1,153 Intersegment revenues: December 31, 2018 - Successor $ 6 $ 8 $ 3 $ 435 $ (437 ) $ 15 December 31, 2017 - Successor 6 8 2 53 (19 ) 50 March 24, 2016 to December 31, 2016 - Successor 4 5 2 47 (13 ) 45 January 1, 2016 to March 23, 2016 - Predecessor 1 2 1 — (4 ) — Depreciation and amortization: December 31, 2018 - Successor $ 385 $ 182 $ 136 $ 37 $ — $ 740 December 31, 2017 - Successor 321 167 146 42 (1 ) $ 675 March 24, 2016 to December 31, 2016 - Successor 224 120 128 43 — $ 515 January 1, 2016 to March 23, 2016 - Predecessor 71 37 37 11 (4 ) $ 152 Operating expenses: December 31, 2018 - Successor $ 1,919 $ 1,143 $ 1,087 $ 442 $ (435 ) $ 4,156 December 31, 2017 - Successor 1,760 1,071 1,029 68 (17 ) $ 3,911 March 24, 2016 to December 31, 2016 - Successor 1,577 952 1,000 33 (13 ) $ 3,549 January 1, 2016 to March 23, 2016 - Predecessor 443 284 251 73 (3 ) $ 1,048 Pepco DPL ACE Other (b) Intersegment PHI Interest expense, net: December 31, 2018 - Successor $ 128 $ 58 $ 64 $ 11 $ — $ 261 December 31, 2017 - Successor 121 51 61 13 (1 ) $ 245 March 24, 2016 to December 31, 2016 - Successor 98 38 47 12 — $ 195 January 1, 2016 to March 23, 2016 - Predecessor 29 12 15 11 (2 ) $ 65 Income (loss) before income taxes: December 31, 2018 - Successor $ 223 $ 142 $ 87 $ 388 $ (408 ) $ 432 December 31, 2017 - Successor 310 192 103 377 (404 ) $ 578 March 24, 2016 to December 31, 2016 - Successor 36 (30 ) (51 ) (84 ) 71 $ (58 ) January 1, 2016 to March 23, 2016 - Predecessor 47 43 5 59 (118 ) $ 36 Income taxes: December 31, 2018 - Successor $ 13 $ 22 $ 12 $ (10 ) $ (2 ) $ 35 December 31, 2017 - Successor 105 71 26 15 — $ 217 March 24, 2016 to December 31, 2016 - Successor 26 5 (5 ) (23 ) — $ 3 January 1, 2016 to March 23, 2016 - Predecessor 15 17 1 (16 ) — $ 17 Net income (loss): December 31, 2018 - Successor $ 210 $ 120 $ 75 $ (22 ) $ 15 $ 398 December 31, 2017 - Successor 205 121 77 (91 ) 50 $ 362 March 24, 2016 to December 31, 2016 - Successor 10 (35 ) (47 ) (34 ) 45 $ (61 ) January 1, 2016 to March 23, 2016 - Predecessor 32 26 5 (44 ) — $ 19 Capital expenditures: December 31, 2018 - Successor $ 656 $ 364 $ 335 $ 20 $ — $ 1,375 December 31, 2017 - Successor 628 428 312 28 — $ 1,396 March 24, 2016 to December 31, 2016 - Successor 489 277 218 24 — 1,008 January 1, 2016 to March 23, 2016 - Predecessor 97 72 93 11 — 273 Total assets: December 31, 2018 - Successor $ 8,299 $ 4,588 $ 3,699 $ 10,819 $ (5,421 ) $ 21,984 December 31, 2017 - Successor 7,832 4,357 3,445 10,600 (4,987 ) 21,247 __________ (a) Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 23 — Supplemental Financial Information for additional information on total utility taxes. (b) Other primarily includes PHI’s corporate operations, shared service entities and other financing and investment activities. For the predecessor periods presented, Other includes the activity of PHI’s unregulated businesses which were distributed to Exelon and Generation as a result of the PHI Merger. |
Analysis and reconciliation of reportable segment revenues for Generation | Competitive Business Revenues (Generation): 2018 Revenues from external customers (a) Contracts with customers Other (b) Total Intersegment Revenues Total Revenues Mid-Atlantic $ 5,241 $ 233 $ 5,474 $ 13 $ 5,487 Midwest 4,527 190 4,717 (11 ) 4,706 New England 2,660 185 2,845 (4 ) 2,841 New York 1,723 (36 ) 1,687 — 1,687 ERCOT 572 560 1,132 1 1,133 Other Power Regions 870 686 1,556 (62 ) 1,494 Total Competitive Businesses Electric Revenues 15,593 1,818 17,411 (63 ) 17,348 Competitive Businesses Natural Gas Revenues 1,524 1,194 2,718 62 2,780 Competitive Businesses Other Revenues (c) 510 (202 ) 308 1 309 Total Generation Consolidated Operating Revenues 17,627 2,810 $ 20,437 $ — $ 20,437 2017 Revenues from external customers (a) Contracts with customers Other (b) Total Intersegment Revenues Total Revenues Mid-Atlantic $ 5,523 $ (8 ) $ 5,515 $ 25 $ 5,540 Midwest 3,923 283 4,206 (25 ) 4,181 New England 2,064 (54 ) 2,010 (8 ) 2,002 New York 1,605 (38 ) 1,567 (17 ) 1,550 ERCOT 641 317 958 4 962 Other Power Regions 594 482 1,076 (27 ) 1,049 Total Competitive Businesses Electric Revenues 14,350 982 15,332 (48 ) 15,284 Competitive Businesses Natural Gas Revenues 1,658 917 2,575 53 2,628 Competitive Businesses Other Revenues (c) 744 (151 ) 593 (5 ) 588 Total Generation Consolidated Operating Revenues $ 16,752 $ 1,748 $ 18,500 $ — $ 18,500 2016 Revenues from external customers (a) Contracts with customers Other (b) Total Intersegment Revenues Total Revenues Mid-Atlantic $ 6,182 $ 30 $ 6,212 $ (33 ) $ 6,179 Midwest 4,007 395 4,402 10 4,412 New England 1,953 (175 ) 1,778 (9 ) 1,769 New York 1,198 10 1,208 (42 ) 1,166 ERCOT 810 21 831 6 837 Other Power Regions 670 299 969 (62 ) 907 Total Competitive Businesses Electric Revenues 14,820 580 15,400 (130 ) 15,270 Competitive Businesses Natural Gas Revenues 1,953 193 2,146 135 2,281 Competitive Businesses Other Revenues (c) 756 (545 ) 211 (5 ) 206 Total Generation Consolidated Operating Revenues $ 17,529 $ 228 $ 17,757 $ — $ 17,757 __________ (a) Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants. (b) Includes revenues from derivatives and leases. (c) Other represents activities not allocated to a region. See text above for a description of included activities. Includes a $38 million and $52 million decrease to revenues for the amortization of intangible assets and liabilities related to commodity contracts recorded at fair value in 2017 and 2016 , respectively, unrealized mark-to-market losses of $262 million , $131 million , and $500 million in 2018 , 2017 , and 2016 , respectively, and elimination of intersegment revenues. Revenues net of purchased power and fuel expense (Generation): 2018 2017 2016 RNF from external (a) Intersegment Total RNF RNF from external (a) Intersegment RNF Total RNF RNF from external (a) Intersegment Total RNF Mid-Atlantic $ 3,022 $ 51 $ 3,073 $ 3,105 $ 109 $ 3,214 $ 3,282 $ 35 $ 3,317 Midwest 3,112 23 3,135 2,810 10 2,820 2,969 2 2,971 New England 368 (14 ) 354 538 (24 ) 514 467 (29 ) 438 New York 1,112 10 1,122 1,007 1 1,008 771 (19 ) 752 ERCOT 501 (243 ) 258 575 (243 ) 332 412 (131 ) 281 Other Power Regions 515 (140 ) 375 476 (171 ) 305 483 (147 ) 336 Total Revenues net of purchased power and fuel for Reportable Segments $ 8,630 $ (313 ) $ 8,317 $ 8,511 $ (318 ) $ 8,193 $ 8,384 $ (289 ) $ 8,095 Other (b) 114 313 427 299 318 617 543 289 832 Total Generation Revenues net of purchased power and fuel expense $ 8,744 $ — $ 8,744 $ 8,810 $ — $ 8,810 $ 8,927 $ — $ 8,927 __________ (a) Includes purchases and sales from/to third parties and affiliated sales to the Utility Registrants. (b) Other represents activities not allocated to a region. See text above for a description of included activities. Includes a $54 million and $57 million decrease in RNF for the amortization of intangible assets and liabilities related to commodity contracts in 2017 and 2016 , respectively, unrealized mark-to-market losses of $319 million , $175 million , and $41 million in 2018 , 2017 , and 2016 , respectively, accelerated nuclear fuel amortization associated with the announced early plant retirements as discussed in Note 8 - Early Plant Retirements of $57 million , $12 million and $60 million for the year ended December 31, 2018 , 2017 , and 2016 and the elimination of intersegment RNF. |
Schedule of Revenue by Major Customers by Reporting Segments [Table Text Block] | Electric and Gas Revenue by Customer Class (Utility Registrants): 2018 Successor Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 2,942 $ 1,566 $ 1,382 $ 2,351 $ 1,021 $ 669 $ 661 Small commercial & industrial 1,487 404 257 488 140 186 162 Large commercial & industrial 538 223 429 1,124 846 100 178 Public authorities & electric railroads 47 28 28 58 32 14 12 Other (a) 867 243 327 593 193 175 227 Total rate-regulated electric revenues (b) 5,881 2,464 2,423 4,614 2,232 1,144 1,240 Rate-regulated natural gas revenues Residential — 395 491 99 — 99 — Small commercial & industrial — 143 77 44 — 44 — Large commercial & industrial — 1 124 8 — 8 — Transportation — 23 — 16 — 16 — Other (c) — 6 63 13 — 13 — Total rate-regulated natural gas revenues (d) — 568 755 180 — 180 — Total rate-regulated revenues from contracts with customers 5,881 3,032 3,178 4,794 2,232 1,324 1,240 Other revenues Revenues from alternative revenue programs (29 ) (7 ) (26 ) — — 4 (4 ) Other rate-regulated electric revenues (e) 30 12 13 10 7 3 — Other rate-regulated natural gas revenues (e) — 1 4 1 — 1 — Total other revenues 1 6 (9 ) 11 7 8 (4 ) Total rate-regulated revenues for reportable segments $ 5,882 $ 3,038 $ 3,169 $ 4,805 $ 2,239 $ 1,332 $ 1,236 2017 Successor Revenues from contracts with customers ComEd PECO BGE PHI Pepco DPL ACE Rate-regulated electric revenues Residential $ 2,715 $ 1,505 $ 1,365 $ 2,246 $ 964 $ 663 $ 619 Small commercial & industrial 1,363 401 254 490 137 187 166 Large commercial & industrial 455 223 427 1,086 794 103 189 Public authorities & electric railroads 44 30 31 60 33 14 13 Other (a) 886 204 299 541 199 163 191 Total rate-regulated electric revenues (b) 5,463 2,363 2,376 4,423 2,127 1,130 1,178 Rate-regulated natural gas revenues Residential — 331 437 90 — 90 — Small commercial & industrial — 131 75 38 — 38 — Large commercial & industrial — 1 119 8 — 8 — Transportation — 23 — 15 — 15 — Other (c) — 8 28 9 — 9 — Total rate-regulated natural gas revenues (d) — 494 659 160 — 160 — Total rate-regulated revenues from contracts with customers 5,463 2,857 3,035 4,583 2,127 1,290 1,178 Other revenues Revenues from alternative revenue programs 43 — 124 40 26 6 8 Other rate-regulated electric revenues (e) 30 12 13 8 5 3 — Other rate-regulated natural gas revenues (e) — 1 4 1 — 1 — Other revenues (f) — — — 47 — — — Total other revenues 73 13 141 96 31 10 8 Total rate-regulated revenues for reportable segments $ 5,536 $ 2,870 $ 3,176 $ 4,679 $ 2,158 $ 1,300 $ 1,186 Successor Predecessor 2016 March 24, 2016 to December 31, 2016 January 1, 2016 to March 23, 2016 Revenues from contracts with customers ComEd PECO BGE Pepco DPL ACE PHI PHI Rate-regulated electric revenues Residential $ 2,603 $ 1,631 $ 1,504 $ 1,004 $ 672 $ 664 $ 1,779 $ 561 Small commercial & industrial 1,318 430 276 150 188 183 400 121 Large commercial & industrial 462 234 434 790 99 201 835 255 Public authorities & electric railroads 45 32 35 32 13 13 45 13 Other (a) 820 192 276 190 160 187 400 169 Total rate-regulated electric revenues (b) 5,248 2,519 2,525 2,166 1,132 1,248 3,459 1,119 Rate-regulated natural gas revenues Residential — 309 432 — 86 — 50 36 Small commercial & industrial — 121 66 — 35 — 21 14 Large commercial & industrial — — 114 — 6 — 4 2 Transportation — 24 — — 13 — 10 3 Other (c) — 9 28 — 8 — 7 2 Total rate-regulated natural gas revenues (d) — 463 640 — 148 — 92 57 Total rate-regulated revenues from contracts with customers 5,248 2,982 3,165 2,166 1,280 1,248 3,551 1,176 Other revenues Revenues from alternative revenue programs (24 ) — 53 14 (6 ) 9 43 (26 ) Other rate-regulated electric revenues (e) 30 12 13 6 3 — 6 3 Other rate-regulated natural gas revenues (e) — — 2 — — — — — Other revenues (f) — — — — — — 43 — Total other revenues 6 12 68 20 (3 ) 9 92 (23 ) Total rate-regulated revenues for reportable segments $ 5,254 $ 2,994 $ 3,233 $ 2,186 $ 1,277 $ 1,257 $ 3,643 $ 1,153 __________ (a) Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue. (b) Includes operating revenues from affiliates of $ 27 million , $7 million , $8 million , $15 million , $6 million , $8 million and $3 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2018 , $15 million , $6 million , $5 million , $3 million , $6 million , $8 million and $2 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, in 2017 , and $15 million , $7 million , $7 million , $2 million , $5 million , $7 million and $3 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2016 . (c) Includes revenues from off-system natural gas sales. (d) Includes operating revenues from affiliates of $1 million and $21 million at PECO and BGE, respectively, in 2018 , $1 million and $11 million at PECO and BGE, respectively, in 2017 , and $1 million and $14 million at PECO and BGE, respectively, in 2016 . (e) Includes late payment charge revenues. (f) Includes operating revenues from affiliates of $47 million and $43 million at PHI in 2017 and 2016 , respectively. |
Related Party Transactions (Tab
Related Party Transactions (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Related Party Transactions [Abstract] | |
Schedule of Related Party Transactions [Table Text Block] | The financial statements of PECO include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: Generation (a) $ 2 $ 1 $ 3 BSC 3 5 3 ComEd 1 — 1 BGE 1 1 1 ACE 1 — — Total operating revenues from affiliates $ 8 $ 7 $ 8 Purchased power from affiliates Generation (b) $ 126 $ 135 $ 287 Operating and maintenance from affiliates: BSC (c) $ 146 $ 146 $ 142 Generation 2 2 2 ComEd 7 — 1 BGE 1 1 1 Total operating and maintenance from affiliates $ 156 $ 149 $ 146 Interest expense to affiliates, net: PECO Trust III $ 6 $ 6 $ 6 PECO Trust IV 6 6 6 Exelon Corporate 2 — — Generation — (1 ) — Total interest expense to affiliates, net: $ 14 $ 11 $ 12 Capitalized costs BSC (c) $ 64 $ 59 $ 57 Cash dividends paid to parent $ 306 $ 288 $ 277 Contributions from parent $ 89 $ 16 $ 18 PHI The financial statements of PHI include related party transactions as presented in the tables below: Successor For the Year Ended December 31, For the Year Ended December 31, March 24, 2016 to December 31, 2018 2017 2016 Operating revenues from affiliates: BSC $ 12 $ 48 $ 44 PHISCO 1 2 — Generation 2 — 1 Total operating revenues from affiliates $ 15 $ 50 $ 45 Purchased power from affiliates Generation $ 355 $ 463 $ 486 Operating and maintenance from affiliates: BSC (a) $ 147 $ 145 $ 86 Other 5 5 3 Total operating and maintenance from affiliates $ 152 $ 150 $ 89 Earnings (losses) in equity method investments: Other $ 1 $ — $ — Capitalized costs: BSC (a) $ 102 $ — $ — PHISCO (a) 79 — — Total capitalized costs $ 181 $ — $ — Cash dividends paid to parent $ 326 $ 311 $ 273 Contributions from parent $ 385 $ 758 $ 1,251 December 31, 2018 2017 Receivables from affiliates (current): ComEd (a) $ 69 $ 28 PECO (b) 30 26 BGE (c) 24 24 Pepco (d) 28 36 DPL (e) 7 12 ACE (f) 5 6 PHISCO (h) — 1 Other 10 7 Total receivables from affiliates (current) $ 173 $ 140 Intercompany money pool (current): Exelon Corporate $ 100 $ — PCI — 54 Total intercompany money pool (current) $ 100 $ 54 Payables to affiliates (current): Exelon Corporate (i) $ 17 $ 21 BSC (h) 95 74 ComEd 19 12 PECO (b) — 4 Other 8 12 Total payables to affiliates (current) $ 139 $ 123 Other liabilities to affiliates (current): ComEd (a) $ 14 $ — Long-term debt to affiliates (noncurrent): Exelon Corporate (k) $ 898 $ 910 Payables to affiliates (noncurrent): ComEd (j) $ 2,217 $ 2,528 PECO (j) 389 537 Total payables to affiliates (noncurrent) $ 2,606 $ 3,065 __________ (a) Generation has an ICC-approved RFP contract with ComEd to provide a portion of ComEd’s electricity supply requirements. Generation also sells RECs and ZECs to ComEd. (b) Generation provides electric supply to PECO under contracts executed through PECO’s competitive procurement process. In addition, Generation has a ten-year agreement with PECO to sell solar AECs. (c) Generation provides a portion of BGE’s energy requirements under its MDPSC-approved market-based SOS and gas commodity programs. (d) Generation provides electric supply to Pepco under contracts executed through Pepco's competitive procurement process approved by the MDPSC and DCPSC. (e) Generation provides a portion of DPL's energy requirements under its MDPSC and DPSC approved market based SOS and gas commodity programs. (f) Generation provides electric supply to ACE under contracts executed through ACE's competitive procurement process. (g) Generation requires electricity for its own use at its generating stations. Generation purchases electricity and distribution and transmission services from PECO and BGE and only distribution and transmission services from ComEd for the delivery of electricity to its generating stations. (h) Generation receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (i) The balance consists of interest owed to Exelon Corporation related to the senior unsecured notes, as well as, expense related to certain invoices Exelon Corporation processed on behalf of Generation. (j) Generation has long-term payables to ComEd and PECO as a result of the nuclear decommissioning contractual construct whereby, to the extent NDT funds are greater than the underlying ARO at the end of decommissioning, such amounts are due back to ComEd and PECO, as applicable, for payment to their respective customers. See Note 15 — Asset Retirement Obligations for additional information. (k) In connection with the debt obligations assumed by Exelon as part of the Constellation merger, Exelon and subsidiaries of Generation (former Constellation subsidiaries) assumed intercompany loan agreements that mirror the terms and amounts of the third-party debt obligations of Exelon, resulting in intercompany notes payable included in Long-term Debt to affiliates in Generation’s Consolidated Balance Sheets and intercompany notes receivable at Exelon Corporate, which are eliminated in consolidation in Exelon’s Consolidated Balance Sheets. December 31, 2018 2017 Prepaid voluntary employee beneficiary association trust (c) $ 5 $ 2 Receivables from affiliates (current): Voluntary employee beneficiary association trust $ 1 $ 1 Generation 19 12 Total receivables from affiliates (current) $ 20 $ 13 Receivables from affiliates (noncurrent): Generation (d) $ 2,217 $ 2,528 Payables to affiliates (current): Generation (a) $ 55 $ 28 BSC (b) 56 39 ComEd Financing III 4 4 Exelon Corporate 4 3 Total payables to affiliates (current) $ 119 $ 74 Long-term debt to ComEd financing trust: ComEd Financing III $ 205 $ 205 __________ (a) ComEd procures a portion of its electricity supply requirements from Generation under an ICC-approved RFP contract. ComEd also purchases RECs and ZECs from Generation. (b) ComEd receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (c) The voluntary employee benefit association trusts covering active employees are included in corporate operations and are funded by the Registrants. A prepayment to the active welfare plans has accumulated due to actuarially determined contribution rates, which are the basis for ComEd’s contributions to the plans, being higher than actual claim expense incurred by the plans over time. The prepayment is included in other current assets. (d) ComEd has a long-term receivable from Generation as a result of the nuclear decommissioning contractual construct for generating facilities previously owned by ComEd. To the extent the assets associated with decommissioning are greater than the applicable ARO at the end of decommissioning, such amounts are due back to ComEd for payment to ComEd’s customers. December 31, 2018 2017 Receivables from affiliates (current): DPL $ 1 $ — Payables to affiliates (current): Exelon Corporation $ 1 $ — Generation (b) 28 36 BSC (c) 19 11 PHISCO (c) 14 27 Total payables to affiliates (current) $ 62 $ 74 __________ (a) Pepco provides energy to Generation for Generation’s own use. (b) Pepco procures a portion of its electricity supply requirements from Generation under its MDPSC and DCPSC approved market based SOS commodity programs. (c) Pepco receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (d) PES performed underground transmission, distribution construction and maintenance services, including services that are treated as capital costs, for Pepco. The financial statements of DPL include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: BSC $ 1 $ — $ — PHISCO 4 6 5 ComEd 1 — — ACE 1 — — Other 1 2 2 Total operating revenues from affiliates $ 8 $ 8 $ 7 Purchased power from affiliates Generation (a) $ 120 $ 179 $ 154 Operating and maintenance: PHISCO (b), (d) $ — $ 165 $ 194 PES (c) — 9 8 Total operating and maintenance $ — $ 174 $ 202 Operating and maintenance from affiliates: BSC (b) $ 51 $ 31 $ 18 PHISCO (b), (d) 111 — — Other — 1 1 Total operating and maintenance from affiliates $ 162 $ 32 $ 19 Capitalized costs: BSC (b) $ 28 $ — $ — PHISCO (b) 25 — — Total capitalized costs $ 53 $ — $ — Cash dividends paid to parent $ 96 $ 112 $ 54 Contributions from parent $ 150 $ — $ 152 December 31, 2018 2017 Payables to affiliates (current): Generation $ 40 $ 54 BGE — 1 BSC (a) 41 24 Exelon Corporate 6 6 Other 7 5 Total payables to affiliates (current) $ 94 $ 90 __________ (a) PHI receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. December 31, 2018 2017 Payables to affiliates (current): Exelon Corporate $ 1 $ — Generation (a) 7 12 BSC (b) 11 7 PHISCO (b) 12 27 Pepco 1 — ACE 1 — Total payables to affiliates (current) $ 33 $ 46 The financial statements of ComEd include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates Generation $ 9 $ 9 $ 7 BSC 7 6 6 PECO 10 — 1 BGE 1 — 1 Total operating revenues from affiliates $ 27 $ 15 $ 15 Purchased power from affiliates Generation (a) $ 529 $ 108 $ 47 Operating and maintenance from affiliates BSC (b) $ 265 $ 270 $ 225 PECO 1 — 1 BGE 1 — 1 Total operating and maintenance from affiliates $ 267 $ 270 $ 227 Interest expense to affiliates, net: ComEd Financing III $ 13 $ 13 $ 13 Capitalized costs BSC (b) $ 135 $ 118 $ 112 Cash dividends paid to parent $ 459 $ 422 $ 369 Contributions from parent $ 500 $ 651 $ 315 December 31, 2018 2017 Prepaid voluntary employee beneficiary association trust (d) $ 1 $ — Receivables from affiliates (noncurrent): Generation (e) $ 389 $ 537 Payables to affiliates (current): Generation (b) $ 30 $ 22 BSC (c) 26 29 Exelon Corporate 2 1 PECO Trust III 1 1 Total payables to affiliates (current) $ 59 $ 53 Long-term debt to financing trusts: PECO Trust III $ 81 $ 81 PECO Trust IV 103 103 Total long-term debt to financing trusts $ 184 $ 184 __________ (a) PECO provides energy to Generation for Generation’s own use. (b) PECO purchases electric supply from Generation under contracts executed through its competitive procurement process. In addition, PECO has five-year and ten-year agreements with Generation to purchase non-solar and solar AECs, respectively. (c) PECO receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (d) The voluntary employee beneficiary association trusts covering active employees are included in corporate operations and are funded by the Registrants. A prepayment to the active welfare plans has accumulated due to actuarially determined contribution rates, which are the basis for PECO’s contributions to the plans, being higher than actual claim expense incurred by the plans over time. (e) PECO has a long-term receivable from Generation as a result of the nuclear decommissioning contractual construct, whereby, to the extent the assets associated with decommissioning are greater than the applicable ARO at the end of decommissioning, such amounts are due back to PECO for payment to PECO’s customers. The financial statements of BGE include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: Generation (a) $ 22 $ 10 $ 13 BSC 5 5 6 ComEd 1 — 1 PECO 1 1 1 Total operating revenues from affiliates $ 29 $ 16 $ 21 Purchased power from affiliates Generation (b) $ 257 $ 384 $ 604 Operating and maintenance from affiliates: BSC (c) $ 157 $ 152 $ 130 Generation 3 — — ComEd 1 — 1 PECO 1 1 1 Total operating and maintenance from affiliates $ 162 $ 153 $ 132 Interest expense to affiliates, net: BGE Capital Trust II $ — $ 10 $ 16 Capitalized costs BSC (c) $ 79 $ 54 $ 36 Cash dividends paid to parent $ 209 $ 198 $ 179 Contributions from parent $ 109 $ 184 $ 61 December 31, 2018 2017 Receivables from affiliates (current): Other $ 1 $ 1 Payables to affiliates (current): Generation (b) $ 24 $ 24 BSC (c) 38 25 Exelon Corporate 2 1 Other 1 2 Total payables to affiliates (current) $ 65 $ 52 __________ (a) BGE provides energy to Generation for Generation’s own use. (b) BGE procures a portion of its electricity and gas supply requirements from Generation under its MDPSC-approved market-based SOS and gas commodity programs. (c) BGE receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. The financial statements of Generation include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: ComEd (a) $ 523 $ 121 $ 47 PECO (b) 128 138 290 BGE (c) 260 388 608 Pepco (d) 206 255 295 DPL (e) 120 179 154 ACE (f) 29 29 37 BSC 2 1 2 Other — 4 6 Total operating revenues from affiliates $ 1,268 $ 1,115 $ 1,439 Purchased power and fuel from affiliates: ComEd $ (6 ) $ 13 $ — BGE 20 9 12 Other — (3 ) — Total purchased power and fuel from affiliates $ 14 $ 19 $ 12 Operating and maintenance from affiliates: ComEd (g) $ 7 $ 7 $ 7 PECO (g) 2 1 3 BGE (g) 2 1 1 Pepco 1 — 1 PHISCO 1 1 1 BSC (h) 652 689 650 Other (4 ) (2 ) — Total operating and maintenance from affiliates $ 661 $ 697 $ 663 Interest expense to affiliates, net: Exelon Corporate (i) $ 36 $ 37 $ 39 PCI — 1 — PECO — 1 — Total interest expense to affiliates, net: $ 36 $ 39 $ 39 Earnings (losses) in equity method investments Qualifying facilities and domestic power projects $ (30 ) $ (33 ) $ (25 ) Capitalized costs BSC (h) $ 67 $ 98 $ 98 Cash distributions paid to member $ 1,001 $ 659 $ 922 Contributions from member $ 155 $ 102 $ 142 December 31, 2018 2017 Payables to affiliates (current): ComEd Financing III $ 4 $ 4 PECO Trust III 1 1 Total payables to affiliates (current) $ 5 $ 5 Long-term debt to financing trusts: ComEd Financing III $ 206 $ 205 PECO Trust III 81 81 PECO Trust IV 103 103 Total long-term debt to financing trusts $ 390 $ 389 __________ (a) The intersegment profit associated with the sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory authoritative guidance. For Exelon, these amounts are included in operating revenues in the Consolidated Statements of Operations. See Note 4 — Regulatory Matters for additional information. The financial statements of Pepco include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: Generation (a) $ 1 $ — $ 1 BSC 1 — — PHISCO 4 6 4 Total operating revenues from affiliates $ 6 $ 6 $ 5 Purchased power from affiliates Generation (b) $ 206 $ 255 $ 295 Operating and maintenance: PHISCO (c), (e) $ — $ 219 $ 263 PES (d) — 29 39 Total operating and maintenance $ — $ 248 $ 302 Operating and maintenance from affiliates: BSC (c) $ 89 $ 53 $ 31 PHISCO (c), (e) 137 5 4 Total operating and maintenance from affiliates $ 226 $ 58 $ 35 Capitalized costs: BSC (c) $ 40 $ — $ — PHISCO (c) 32 — — Total capitalized costs $ 72 $ — $ — Cash dividends paid to parent $ 169 $ 133 $ 136 Contributions from parent $ 166 $ 161 $ 187 The financial statements of Exelon include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: Generation (a) (2 ) — PECO (a) — 1 1 BGE (a) — 4 4 ACE (a) — — — Other 1 2 5 Total operating revenues from affiliates $ (1 ) $ 7 $ 10 Interest expense to affiliates, net: ComEd Financing III $ 13 $ 14 $ 13 PECO Trust III 6 6 6 PECO Trust IV 6 6 6 BGE Capital Trust II — 10 16 Total interest expense to affiliates, net $ 25 $ 36 $ 41 Earnings (losses) in equity method investments: Qualifying facilities and domestic power projects $ (29 ) $ (33 ) $ (25 ) Other 1 1 1 Total losses in equity method investments $ (28 ) $ (32 ) $ (24 ) ACE The financial statements of ACE include related party transactions as presented in the tables below: For the Years Ended December 31, 2018 2017 2016 Operating revenues from affiliates: PHISCO $ 2 $ 1 $ 2 Other 1 1 1 Total operating revenues from affiliates $ 3 $ 2 $ 3 Purchased power from affiliates Generation (a) $ 29 $ 29 $ 37 Operating and maintenance: PHISCO (b), (c) $ — $ 135 $ 155 Operating and maintenance from affiliates: BSC (b) $ 42 $ 25 $ 15 PHISCO (b), (c) 98 — — Other 2 3 3 Total operating and maintenance from affiliates $ 142 $ 28 $ 18 Capitalized costs: BSC (b) $ 20 $ — $ — PHISCO (b) 21 — — Total capitalized costs $ 41 $ — $ — Cash dividends paid to parent $ 59 $ 68 $ 63 Contributions from parent $ 67 $ — $ 139 December 31, 2018 2017 Receivable from affiliate (current): DPL $ 1 $ — Payables to affiliates (current): Generation (a) $ 5 $ 6 BSC (b) 8 5 PHISCO (b) 13 18 Other 2 — Total payables to affiliates (current) $ 28 $ 29 __________ (a) ACE purchases electric supply from Generation under contracts executed through its competitive procurement process. (b) ACE receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. (c) Due to the PHI entities' system conversion to Exelon's accounting systems on January 1, 2018, corporate support services received from PHISCO are reported in Operating and maintenance from affiliates in 2018. |
Quarterly Data (Unaudited) (Tab
Quarterly Data (Unaudited) (Tables) | 12 Months Ended |
Dec. 31, 2018 | |
Quarterly Financial Data [Abstract] | |
Quarterly Financial Information | The data shown below includes all adjustments that BGE considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 977 $ 951 $ 177 $ 228 $ 128 $ 125 June 30 662 674 85 98 51 45 September 30 731 738 103 124 63 62 December 31 799 813 109 163 71 76 The data shown below includes all adjustments that ACE considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income (Loss) 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 310 $ 275 $ 23 $ 25 $ 7 $ 28 June 30 265 270 25 25 8 8 September 30 406 370 84 79 61 41 December 31 254 271 14 28 (1 ) — The data shown below includes all adjustments that PHI considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income Attributable to Membership Interest 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 1,251 $ 1,175 $ 126 $ 180 $ 65 $ 140 June 30 1,076 1,074 153 148 84 66 September 30 1,361 1,310 245 285 187 153 December 31 1,117 1,121 126 159 62 4 The data shown below includes all adjustments that DPL considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 384 $ 362 $ 49 $ 78 $ 31 $ 57 June 30 289 282 42 41 26 19 September 30 328 327 51 59 33 31 December 31 331 330 48 52 30 14 The data shown below includes all adjustments that ComEd considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 1,512 $ 1,298 $ 292 $ 314 $ 165 $ 141 June 30 1,398 1,357 288 319 164 118 September 30 1,598 1,571 323 404 193 189 December 31 1,373 1,309 242 286 141 120 The data shown below includes all adjustments that Pepco considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 557 $ 530 $ 56 $ 79 $ 31 $ 58 June 30 523 514 85 84 54 43 September 30 628 604 112 149 89 87 December 31 531 510 65 87 36 17 The data shown below, which may not equal the total for the year due to the effects of rounding and dilution, includes all adjustments that Exelon considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 9,693 $ 8,747 $ 1,101 $ 1,308 $ 585 $ 990 June 30 8,076 7,665 942 300 539 95 September 30 9,403 8,768 1,146 1,499 733 823 December 31 8,814 8,384 708 1,288 152 1,880 Net Income Net Income 2018 2017 2018 2017 Quarter ended: March 31 $ 0.61 $ 1.07 $ 0.60 $ 1.06 June 30 0.56 0.10 0.56 0.10 September 30 0.76 0.86 0.76 0.85 December 31 0.16 1.95 0.16 1.94 The data shown below includes all adjustments that PECO considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income Net Income 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 866 $ 796 $ 142 $ 192 $ 113 $ 127 June 30 653 630 127 137 96 88 September 30 757 715 154 169 126 112 December 31 765 729 165 157 124 107 The data shown below includes all adjustments that Generation considers necessary for a fair presentation of such amounts: Operating Revenues Operating Income (Loss) Net Income (Loss) 2018 2017 2018 2017 2018 2017 Quarter ended: March 31 $ 5,512 $ 4,878 $ 347 $ 373 $ 136 $ 418 June 30 4,579 4,216 282 (427 ) 178 (235 ) September 30 5,278 4,750 311 497 234 304 December 31 5,069 4,657 35 504 (178 ) 2,224 |
Significant Accounting Polici_4
Significant Accounting Policies - Narrative (Details) - USD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Significant Accounting Policies Additional Narrative Information [Line Items] | ||
Stockholders' Equity Attributable to Noncontrolling Interest | $ 2,306 | $ 2,291 |
Percentage ownership of consolidated subsidiaries | 100.00% | |
Minimum expectation of tax position to be realized | 50.00% | |
Commonwealth Edison Company [Member] | ||
Significant Accounting Policies Additional Narrative Information [Line Items] | ||
Stockholders' Equity Attributable to Noncontrolling Interest | $ 1 | |
Percentage ownership of consolidated subsidiaries | 99.00% | |
CENG [Member] | ||
Significant Accounting Policies Additional Narrative Information [Line Items] | ||
Ownership interest | 50.01% | |
ExGen Renewables [Member] | ||
Significant Accounting Policies Additional Narrative Information [Line Items] | ||
Ownership interest | 51.00% | |
Minimum [Member] | ||
Significant Accounting Policies Additional Narrative Information [Line Items] | ||
Ownership interest | 20.00% | |
Maximum [Member] | ||
Significant Accounting Policies Additional Narrative Information [Line Items] | ||
Ownership interest | 50.00% |
Significant Accounting Polici_5
Significant Accounting Policies Balance Sheet Classification of Deferred Taxes (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 |
Other noncurrent assets | $ 1,575 | $ 1,330 |
Other noncurrent liabilities | 2,130 | 2,097 |
Commonwealth Edison Co [Member] | ||
Other noncurrent assets | 395 | 238 |
Other noncurrent liabilities | 630 | 562 |
Exelon Generation Co L L C [Member] | ||
Other noncurrent assets | 755 | 670 |
Other noncurrent liabilities | 610 | 658 |
PECO Energy Co [Member] | ||
Other noncurrent assets | 27 | 12 |
Other noncurrent liabilities | 76 | 86 |
Baltimore Gas and Electric Company [Member] | ||
Other noncurrent assets | 5 | 4 |
Other noncurrent liabilities | $ 73 | $ 56 |
Significant Accounting Polici_6
Significant Accounting Policies Revenue Initial Application Period Cumulative Effect Transition (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||||||||||
Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2017 | Jun. 30, 2017 | Mar. 31, 2017 | Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | $ 19,168 | $ 17,394 | $ 16,330 | ||||||||||
Regulated Operating Revenue | (16,879) | (15,964) | (14,988) | ||||||||||
Electric Revenue | 0 | 0 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 0 | 0 | |||||||||||
Revenues | $ 8,814 | $ 9,403 | $ 8,076 | $ 9,693 | $ 8,384 | $ 8,768 | $ 7,665 | $ 8,747 | 35,985 | 33,565 | 31,366 | ||
Revenue from Contract with Customer, Including Assessed Tax | (62) | 207 | 48 | ||||||||||
Accounting Standards Update 2014-09 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Calculated under Revenue Guidance in Effect before Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 17,360 | 16,324 | |||||||||||
Regulated Operating Revenue | (16,171) | (15,036) | |||||||||||
Electric Revenue | 0 | 0 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 0 | 0 | |||||||||||
Revenues | 33,531 | 31,360 | |||||||||||
Calculated under Revenue Guidance in Effect before Topic 606 [Member] | Accounting Standards Update 2014-09 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 34 | 6 | |||||||||||
Regulated Operating Revenue | 207 | 48 | |||||||||||
Electric Revenue | 0 | 0 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 0 | 0 | |||||||||||
Revenues | 34 | 6 | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 207 | 48 | |||||||||||
Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | Accounting Standards Update 2014-09 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Exelon Generation Co L L C [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 19,169 | 17,385 | 16,318 | ||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 0 | 0 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 1,268 | 1,115 | 1,439 | ||||||||||
Revenues | 5,069 | 5,278 | 4,579 | 5,512 | 4,657 | 4,750 | 4,216 | 4,878 | 20,437 | 18,500 | 17,757 | ||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | |||||||||||
Exelon Generation Co L L C [Member] | Accounting Standards Update 2014-09 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Exelon Generation Co L L C [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 17,351 | 16,312 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 0 | 0 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 1,115 | 1,439 | |||||||||||
Revenues | 18,466 | 17,751 | |||||||||||
Exelon Generation Co L L C [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member] | Accounting Standards Update 2014-09 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Exelon Generation Co L L C [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 34 | 6 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 0 | 0 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 0 | 0 | |||||||||||
Revenues | 34 | 6 | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | |||||||||||
Exelon Generation Co L L C [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | Accounting Standards Update 2014-09 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Commonwealth Edison Co [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 5,884 | 5,478 | 5,263 | ||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 27 | 15 | 15 | ||||||||||
Revenues | 1,373 | 1,598 | 1,398 | 1,512 | 1,309 | 1,571 | 1,357 | 1,298 | 5,882 | 5,536 | 5,254 | ||
Revenue from Contract with Customer, Including Assessed Tax | (29) | 43 | (24) | ||||||||||
Commonwealth Edison Co [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 5,521 | 5,239 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 15 | 15 | |||||||||||
Revenues | 5,536 | 5,254 | |||||||||||
Commonwealth Edison Co [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | (43) | 24 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 0 | 0 | |||||||||||
Revenues | 0 | 0 | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 43 | (24) | |||||||||||
PECO Energy Co [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 2,469 | 2,369 | 2,524 | ||||||||||
Gas Domestic Regulated Revenue | 568 | 494 | 462 | ||||||||||
Operating revenues from affiliates | 8 | 7 | 8 | ||||||||||
Revenues | 765 | 757 | 653 | 866 | 729 | 715 | 630 | 796 | 3,038 | 2,870 | 2,994 | ||
Revenue from Contract with Customer, Including Assessed Tax | (7) | 0 | 0 | ||||||||||
PECO Energy Co [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 2,369 | 2,524 | |||||||||||
Gas Domestic Regulated Revenue | 494 | 462 | |||||||||||
Operating revenues from affiliates | 7 | 8 | |||||||||||
Revenues | 2,870 | 2,994 | |||||||||||
PECO Energy Co [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 0 | 0 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 0 | 0 | |||||||||||
Revenues | 0 | 0 | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 0 | |||||||||||
Baltimore Gas and Electric Company [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 2,428 | 2,384 | 2,531 | ||||||||||
Gas Domestic Regulated Revenue | 738 | 652 | 628 | ||||||||||
Operating revenues from affiliates | 29 | 16 | 21 | ||||||||||
Revenues | 799 | 731 | 662 | 977 | 813 | 738 | 674 | 951 | 3,169 | 3,176 | 3,233 | ||
Revenue from Contract with Customer, Including Assessed Tax | (26) | 124 | 53 | ||||||||||
Baltimore Gas and Electric Company [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 2,484 | 2,603 | |||||||||||
Gas Domestic Regulated Revenue | 676 | 609 | |||||||||||
Operating revenues from affiliates | 16 | 21 | |||||||||||
Revenues | 3,176 | 3,233 | |||||||||||
Baltimore Gas and Electric Company [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | (100) | (72) | |||||||||||
Gas Domestic Regulated Revenue | (24) | 19 | |||||||||||
Operating revenues from affiliates | 0 | ||||||||||||
Revenues | 0 | 0 | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 124 | 53 | |||||||||||
Pepco Holdings LLC [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electric Revenue | 4,609 | 4,428 | |||||||||||
Gas Domestic Regulated Revenue | 181 | 161 | |||||||||||
Operating revenues from affiliates | 15 | 50 | |||||||||||
Revenues | 1,117 | 1,361 | 1,076 | 1,251 | 1,121 | 1,310 | 1,074 | 1,175 | 4,805 | 4,679 | |||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 40 | |||||||||||
Potomac Electric Power Company [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 2,233 | 2,126 | 2,167 | ||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 6 | 6 | 5 | ||||||||||
Revenues | 531 | 628 | 523 | 557 | 510 | 604 | 514 | 530 | 2,239 | 2,158 | 2,186 | ||
Revenue from Contract with Customer, Including Assessed Tax | 0 | 26 | 14 | ||||||||||
Potomac Electric Power Company [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 2,152 | 2,181 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 6 | 5 | |||||||||||
Revenues | 2,158 | 2,186 | |||||||||||
Potomac Electric Power Company [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | (26) | (14) | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 0 | 0 | |||||||||||
Revenues | 0 | 0 | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 26 | 14 | |||||||||||
Delmarva Power & Light Company [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 1,139 | 1,125 | 1,128 | ||||||||||
Gas Domestic Regulated Revenue | 181 | 161 | 148 | ||||||||||
Operating revenues from affiliates | 8 | 8 | 7 | ||||||||||
Revenues | 331 | 328 | 289 | 384 | 330 | 327 | 282 | 362 | 1,332 | 1,300 | 1,277 | ||
Revenue from Contract with Customer, Including Assessed Tax | 4 | 6 | (6) | ||||||||||
Delmarva Power & Light Company [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 1,131 | 1,122 | |||||||||||
Gas Domestic Regulated Revenue | 161 | 148 | |||||||||||
Operating revenues from affiliates | 8 | 7 | |||||||||||
Revenues | 1,300 | 1,277 | |||||||||||
Delmarva Power & Light Company [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | (6) | 6 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 0 | 0 | |||||||||||
Revenues | 0 | 0 | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 6 | (6) | |||||||||||
Atlantic City Electric Company [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 1,237 | 1,176 | 1,245 | ||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 3 | 2 | 3 | ||||||||||
Revenues | $ 254 | $ 406 | $ 265 | $ 310 | $ 271 | $ 370 | $ 270 | $ 275 | 1,236 | 1,186 | 1,257 | ||
Revenue from Contract with Customer, Including Assessed Tax | (4) | 8 | 9 | ||||||||||
Atlantic City Electric Company [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 1,184 | 1,254 | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 2 | 3 | |||||||||||
Revenues | 1,186 | 1,257 | |||||||||||
Atlantic City Electric Company [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | (8) | (9) | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 0 | 0 | |||||||||||
Revenues | 0 | 0 | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 8 | $ 9 | |||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | $ 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 3,463 | 4,428 | |||||||||||
Gas Domestic Regulated Revenue | 92 | 161 | |||||||||||
Operating revenues from affiliates | 45 | $ 15 | 50 | ||||||||||
Revenues | 3,643 | 4,679 | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | 43 | 40 | |||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | 3,506 | 4,468 | |||||||||||
Gas Domestic Regulated Revenue | 92 | 161 | |||||||||||
Operating revenues from affiliates | 45 | 50 | |||||||||||
Revenues | 3,643 | 4,679 | |||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | 0 | |||||||||||
Regulated Operating Revenue | 0 | 0 | |||||||||||
Electric Revenue | (43) | (40) | |||||||||||
Gas Domestic Regulated Revenue | 0 | 0 | |||||||||||
Operating revenues from affiliates | 0 | 0 | |||||||||||
Revenues | 0 | 0 | |||||||||||
Revenue from Contract with Customer, Including Assessed Tax | $ 43 | $ 40 | |||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | $ 0 | ||||||||||||
Regulated Operating Revenue | 0 | ||||||||||||
Electric Revenue | 1,122 | ||||||||||||
Gas Domestic Regulated Revenue | 57 | ||||||||||||
Operating revenues from affiliates | 0 | ||||||||||||
Revenues | 1,153 | ||||||||||||
Revenue from Contract with Customer, Including Assessed Tax | (26) | ||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Calculated under Revenue Guidance in Effect before Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | ||||||||||||
Regulated Operating Revenue | 0 | ||||||||||||
Electric Revenue | 1,096 | ||||||||||||
Gas Domestic Regulated Revenue | 57 | ||||||||||||
Operating revenues from affiliates | 0 | ||||||||||||
Revenues | 1,153 | ||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Difference between Revenue Guidance in Effect before and after Topic 606 [Member] | |||||||||||||
Revenue, Initial Application Period Cumulative Effect Transition [Line Items] | |||||||||||||
Electrical Generation Revenue | 0 | ||||||||||||
Regulated Operating Revenue | 0 | ||||||||||||
Electric Revenue | 26 | ||||||||||||
Gas Domestic Regulated Revenue | 0 | ||||||||||||
Operating revenues from affiliates | 0 | ||||||||||||
Revenues | 0 | ||||||||||||
Revenue from Contract with Customer, Including Assessed Tax | $ (26) |
Significant Accounting Polici_7
Significant Accounting Policies Expected Right of Use Assets and Lease Obligations (Details) | 12 Months Ended |
Dec. 31, 2018 | |
Estimated Right of Use Assets and Lease Liabilities from Operating Leases [Line Items] | |
Estimated Operating Lease, Right-of-Use Asset | $1,400-$1,500 |
Estimated Operating Lease, Lease Liability | $1,600-$1,700 |
Exelon Generation Co L L C [Member] | |
Estimated Right of Use Assets and Lease Liabilities from Operating Leases [Line Items] | |
Estimated Operating Lease, Right-of-Use Asset | $1,000-$1,100 |
Estimated Operating Lease, Lease Liability | $1,200-$1,300 |
Commonwealth Edison Co [Member] | |
Estimated Right of Use Assets and Lease Liabilities from Operating Leases [Line Items] | |
Estimated Operating Lease, Right-of-Use Asset | $5-$10 |
Estimated Operating Lease, Lease Liability | $5-$10 |
PECO Energy Co [Member] | |
Estimated Right of Use Assets and Lease Liabilities from Operating Leases [Line Items] | |
Estimated Operating Lease, Right-of-Use Asset | $1-$5 |
Estimated Operating Lease, Lease Liability | $1-$5 |
Baltimore Gas and Electric Company [Member] | |
Estimated Right of Use Assets and Lease Liabilities from Operating Leases [Line Items] | |
Estimated Operating Lease, Right-of-Use Asset | $100-$120 |
Estimated Operating Lease, Lease Liability | $100-$120 |
Pepco Holdings LLC [Member] | |
Estimated Right of Use Assets and Lease Liabilities from Operating Leases [Line Items] | |
Estimated Operating Lease, Right-of-Use Asset | $250-$270 |
Estimated Operating Lease, Lease Liability | $300-$320 |
Potomac Electric Power Company [Member] | |
Estimated Right of Use Assets and Lease Liabilities from Operating Leases [Line Items] | |
Estimated Operating Lease, Right-of-Use Asset | $60-$65 |
Estimated Operating Lease, Lease Liability | $60-$65 |
Delmarva Power & Light Company [Member] | |
Estimated Right of Use Assets and Lease Liabilities from Operating Leases [Line Items] | |
Estimated Operating Lease, Right-of-Use Asset | $70-$75 |
Estimated Operating Lease, Lease Liability | $75-$80 |
Atlantic City Electric Company [Member] | |
Estimated Right of Use Assets and Lease Liabilities from Operating Leases [Line Items] | |
Estimated Operating Lease, Right-of-Use Asset | $20-$25 |
Estimated Operating Lease, Lease Liability | $20-$25 |
Variable Interest Entities Vari
Variable Interest Entities Variable Interest Entities - Narrative (Details) $ in Millions | 1 Months Ended | 12 Months Ended | |||||||
Jul. 31, 2017USD ($) | Nov. 30, 2015 | Jun. 30, 2015 | Jul. 30, 2014 | Dec. 31, 2018USD ($)VIEproject | Dec. 31, 2017USD ($)VIE | Dec. 31, 2016USD ($) | Jul. 18, 2014USD ($) | Apr. 01, 2014USD ($) | |
Variable Interest Entity [Line Items] | |||||||||
Number of variable interest entities consolidated | VIE | 5 | 5 | |||||||
Number of variable interest entities not consolidated by equity holders | VIE | 7 | 7 | |||||||
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets and Liabilities, Net | $ 15 | ||||||||
Guarantee obligations maximum exposure | 61 | ||||||||
Variable Interest Entity, Reporting Entity Involvement, Maximum Loss Exposure, Amount | 15 | ||||||||
2015 ESA Investco, LLC [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 99.00% | ||||||||
Payment Guarantee [Member] | CENG [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Guarantee obligations maximum exposure | $ 245 | ||||||||
Financial Guarantee [Member] | CENG [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Guarantee obligations maximum exposure | 165 | ||||||||
Equity interest member [Member] | 2015 ESA Investco, LLC [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 90.00% | ||||||||
Exelon Generation Co L L C [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets and Liabilities, Net | 13 | ||||||||
Parental guarantee provided | $ 34 | ||||||||
Ownership Percentage Of Consolidated Variable Interest Entities | 62.00% | ||||||||
Wind project entities with noncontrolling equity interests | project | 4 | ||||||||
Noncontrolling equity interest ownership percentage held by third parties | 1.00% | ||||||||
Number of projects with significant economic power | project | 3 | ||||||||
Ownership interests in project entities | 99.00% | ||||||||
Variable Interest Entity, Reporting Entity Involvement, Maximum Loss Exposure, Amount | $ 13 | ||||||||
Exelon Generation Co L L C [Member] | ExGen Renewables Holdings, LLC [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Proceeds from Sale of Interest in Partnership Unit | $ 400 | ||||||||
Exelon Generation Co L L C [Member] | Exelon Generation Co L L C [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 100.00% | ||||||||
Ownership Percentage Of Consolidated Variable Interest Entities | 100.00% | ||||||||
Exelon Generation Co L L C [Member] | Equity Method Investment Variable Interest Entities [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Parental guarantee provided | $ 275 | ||||||||
Exelon Generation Co L L C [Member] | CENG [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Parental guarantee provided | $ 688 | ||||||||
Ownership interest | 50.01% | ||||||||
Due from Affiliates | $ 196 | $ 400 | |||||||
Exelon Generation Co L L C [Member] | Distributed Energy Company [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 90.00% | ||||||||
Equity Method Investment, Summarized Financial Information, Equity Excluding Noncontrolling Interests | 227 | $ 85 | |||||||
Exelon Generation Co L L C [Member] | Equity interest member [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 69.00% | ||||||||
Exelon Generation Co L L C [Member] | Equity interest member [Member] | ExGen Renewables Holdings, LLC [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 49.00% | ||||||||
Exelon Generation Co L L C [Member] | Equity interest member [Member] | Distributed Energy Company [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 90.00% | ||||||||
Atlantic City Electric Company [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Guarantee obligations maximum exposure | 16 | ||||||||
Atlantic City Electric Company [Member] | ATF [Member] | |||||||||
Variable Interest Entity [Line Items] | |||||||||
Cash Remitted To VIE | $ 30 | $ 48 | $ 60 |
Variable Interest Entities Va_2
Variable Interest Entities Variable Interest Entities - Carrying Amounts and Classification of Consolidated VIE Assets and Liabilities (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Variable Interest Entity [Line Items] | |||
Current assets | [1] | $ 938 | $ 662 |
Noncurrent assets | [1] | 9,071 | 9,317 |
Total assets | [1] | 10,009 | 9,979 |
Current liabilities | [1] | 274 | 308 |
Noncurrent liabilities | [1] | 3,280 | 3,316 |
Total liabilities | [1] | 3,554 | 3,624 |
Exelon Generation Co L L C [Member] | |||
Variable Interest Entity [Line Items] | |||
Current assets | 931 | 652 | |
Noncurrent assets | 9,045 | 9,286 | |
Total assets | 9,976 | 9,938 | |
Current liabilities | 252 | 272 | |
Noncurrent liabilities | 3,233 | 3,250 | |
Total liabilities | 3,485 | 3,522 | |
Pepco Holdings LLC [Member] | |||
Variable Interest Entity [Line Items] | |||
Current assets | [1] | 7 | 10 |
Noncurrent assets | [1] | 26 | 31 |
Total assets | [1] | 33 | 41 |
Current liabilities | [1] | 22 | 36 |
Noncurrent liabilities | [1] | 47 | 66 |
Total liabilities | [1] | 69 | 102 |
Atlantic City Electric Company [Member] | |||
Variable Interest Entity [Line Items] | |||
Current assets | 4 | 6 | |
Noncurrent assets | 19 | 23 | |
Total assets | 23 | 29 | |
Current liabilities | 19 | 32 | |
Noncurrent liabilities | 40 | 58 | |
Total liabilities | $ 59 | $ 90 | |
[1] | Includes certain purchase accounting adjustments not pushed down to the ACE standalone entity. |
Variable Interest Entities Va_3
Variable Interest Entities Variable Interest Entities - Assets and Liabilities of VIEs which Creditors or Beneficiaries have No Recourse (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Dec. 31, 2015 | |
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | $ 1,349 | $ 898 | $ 635 | $ 6,502 | |
Restricted cash | 247 | 207 | 253 | 205 | |
Customer | 4,607 | 4,445 | |||
Other | 1,256 | 1,132 | |||
Mark-to-market derivative assets, current | 804 | 976 | |||
Other current assets | 1,238 | 1,260 | |||
Total current assets | 13,360 | 11,896 | |||
Property, plant and equipment, net | 76,707 | 74,202 | |||
Nuclear decommissioning trust funds | 11,661 | 13,272 | |||
Goodwill | 6,677 | 6,677 | 6,677 | ||
Mark-to-market derivative assets, noncurrent | 452 | 337 | |||
Other noncurrent assets | 1,575 | 1,330 | |||
Total assets | [1] | 119,666 | 116,770 | ||
Long-term debt due within one year | 1,349 | 2,088 | |||
Accounts payable | 3,800 | 3,532 | |||
Accrued expenses | 2,112 | 1,837 | |||
Mark-to-market derivative liabilities, current | 475 | 232 | |||
Unamortized energy contract liabilities | 149 | 231 | |||
Other current liabilities | 1,035 | 1,069 | |||
Total current liabilities | 11,404 | 10,798 | |||
Long-term debt | 34,075 | 32,176 | |||
Asset retirement obligations | 9,679 | 10,029 | |||
Pension obligations | 3,988 | 3,736 | |||
Unamortized energy contract liabilities | 463 | 609 | |||
Other noncurrent liabilities | 2,130 | 2,097 | |||
Total liabilities | [1] | 86,596 | 84,583 | ||
Variable Interest Entity, Primary Beneficiary [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | [2] | 414 | 126 | ||
Restricted cash | [2] | 66 | 64 | ||
Customer | [2] | 146 | 170 | ||
Other | [2] | 23 | 25 | ||
Materials and supplies | [2] | 212 | 205 | ||
Other current assets | [2] | 52 | 45 | ||
Total current assets | [2] | 913 | 635 | ||
Property, plant and equipment, net | [2] | 6,145 | 6,186 | ||
Nuclear decommissioning trust funds | [2] | 2,351 | 2,502 | ||
Other noncurrent assets | [2] | 258 | 274 | ||
Total noncurrent assets | [2] | 8,754 | 8,962 | ||
Total assets | [2] | 9,667 | 9,597 | ||
Long-term debt due within one year | [2] | 87 | 102 | ||
Accounts payable | [2] | 96 | 114 | ||
Accrued expenses | [2] | 72 | 67 | ||
Unamortized energy contract liabilities | [2] | 15 | 18 | ||
Other current liabilities | [2] | 3 | 7 | ||
Total current liabilities | [2] | 273 | 308 | ||
Long-term debt | [2] | 1,072 | 1,154 | ||
Asset retirement obligations | [2] | 2,160 | 2,035 | ||
Unamortized energy contract liabilities | 1 | ||||
Other noncurrent liabilities | [2] | 42 | 121 | ||
Total noncurrent liabilities | [2] | 3,275 | 3,310 | ||
Total liabilities | [2] | 3,548 | 3,618 | ||
Exelon Generation Co L L C [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 750 | 416 | 290 | 431 | |
Restricted cash | 153 | 138 | 158 | 123 | |
Customer | 2,941 | 2,697 | |||
Other | 562 | 321 | |||
Mark-to-market derivative assets, current | 804 | 976 | |||
Other current assets | 883 | 933 | |||
Total current assets | 8,433 | 6,882 | |||
Property, plant and equipment, net | 23,981 | 24,906 | |||
Nuclear decommissioning trust funds | 11,661 | 13,272 | |||
Goodwill | 47 | 47 | |||
Mark-to-market derivative assets, noncurrent | 452 | 334 | |||
Other noncurrent assets | 755 | 670 | |||
Total assets | [3] | 47,556 | 48,457 | ||
Long-term debt due within one year | 906 | 346 | |||
Accounts payable | 1,847 | 1,773 | |||
Accrued expenses | 898 | 1,022 | |||
Mark-to-market derivative liabilities, current | 449 | 211 | |||
Unamortized energy contract liabilities | 31 | 43 | |||
Other current liabilities | 279 | 265 | |||
Total current liabilities | 5,769 | 4,191 | |||
Long-term debt | 6,989 | 7,734 | |||
Asset retirement obligations | 9,450 | 9,844 | |||
Unamortized energy contract liabilities | 20 | 48 | |||
Other noncurrent liabilities | 610 | 658 | |||
Total liabilities | [3] | 32,048 | 32,498 | ||
Exelon Generation Co L L C [Member] | Variable Interest Entity, Primary Beneficiary [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 414 | 126 | |||
Restricted cash | 62 | 58 | |||
Customer | 146 | 170 | |||
Other | 23 | 25 | |||
Materials and supplies | 212 | 205 | |||
Other current assets | 49 | 41 | |||
Total current assets | 906 | 625 | |||
Property, plant and equipment, net | 6,145 | 6,186 | |||
Nuclear decommissioning trust funds | 2,351 | 2,502 | |||
Other noncurrent assets | 232 | 243 | |||
Total noncurrent assets | 8,728 | 8,931 | |||
Total assets | 9,634 | 9,556 | |||
Long-term debt due within one year | 66 | 67 | |||
Accounts payable | 96 | 114 | |||
Accrued expenses | 72 | 66 | |||
Unamortized energy contract liabilities | 15 | 18 | |||
Other current liabilities | 3 | 7 | |||
Total current liabilities | 252 | 272 | |||
Long-term debt | 1,025 | 1,088 | |||
Asset retirement obligations | 2,160 | 2,035 | |||
Unamortized energy contract liabilities | 1 | ||||
Other noncurrent liabilities | 42 | 121 | |||
Total noncurrent liabilities | 3,228 | 3,244 | |||
Total liabilities | 3,480 | 3,516 | |||
Pepco Holdings LLC [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 124 | 30 | |||
Restricted cash | 43 | 42 | |||
Customer | 453 | 486 | |||
Other | 177 | 206 | |||
Other current assets | 75 | 75 | |||
Total current assets | 1,533 | 1,551 | |||
Property, plant and equipment, net | 13,446 | 12,498 | |||
Goodwill | 4,005 | 4,005 | 4,005 | ||
Other noncurrent assets | 60 | 70 | |||
Total assets | [4] | 21,984 | 21,247 | ||
Long-term debt due within one year | 125 | 396 | |||
Accounts payable | 496 | 348 | |||
Accrued expenses | 256 | 261 | |||
Unamortized energy contract liabilities | 119 | 188 | |||
Other current liabilities | 123 | 123 | |||
Total current liabilities | 1,592 | 1,931 | |||
Long-term debt | 6,134 | 5,478 | |||
Asset retirement obligations | 52 | 16 | |||
Unamortized energy contract liabilities | 442 | 561 | |||
Other noncurrent liabilities | 369 | 389 | |||
Total liabilities | [4] | 12,702 | 12,422 | ||
Pepco Holdings LLC [Member] | Successor [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 170 | ||||
Restricted cash | 43 | ||||
Pepco Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | [2] | 0 | 0 | ||
Restricted cash | [2] | 4 | 6 | ||
Customer | [2] | 0 | 0 | ||
Other | [2] | 0 | 0 | ||
Materials and supplies | [2] | 0 | 0 | ||
Other current assets | [2] | 3 | 4 | ||
Total current assets | [2] | 7 | 10 | ||
Property, plant and equipment, net | [2] | 0 | 0 | ||
Nuclear decommissioning trust funds | [2] | 0 | 0 | ||
Other noncurrent assets | [2] | 26 | 31 | ||
Total noncurrent assets | [2] | 26 | 31 | ||
Total assets | [2] | 33 | 41 | ||
Long-term debt due within one year | [2] | 21 | 35 | ||
Accounts payable | [2] | 0 | 0 | ||
Accrued expenses | [2] | 1 | 1 | ||
Unamortized energy contract liabilities | [2] | 0 | 0 | ||
Other current liabilities | [2] | 0 | 0 | ||
Total current liabilities | [2] | 22 | 36 | ||
Long-term debt | [2] | 47 | 66 | ||
Asset retirement obligations | [2] | 0 | 0 | ||
Unamortized energy contract liabilities | 0 | ||||
Other noncurrent liabilities | [2] | 0 | 0 | ||
Total noncurrent liabilities | [2] | 47 | 66 | ||
Total liabilities | [2] | 69 | 102 | ||
Atlantic City Electric Company [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 7 | 2 | 101 | 3 | |
Restricted cash | 4 | 6 | $ 9 | $ 12 | |
Customer | 95 | 92 | |||
Other | 55 | 56 | |||
Other current assets | 5 | 2 | |||
Total current assets | 240 | 258 | |||
Property, plant and equipment, net | 2,966 | 2,706 | |||
Other noncurrent assets | 40 | 45 | |||
Total assets | [5] | 3,699 | 3,445 | ||
Long-term debt due within one year | 18 | 281 | |||
Accounts payable | 154 | 118 | |||
Accrued expenses | 35 | 33 | |||
Other current liabilities | 4 | 8 | |||
Total current liabilities | 422 | 619 | |||
Long-term debt | 1,170 | 840 | |||
Other noncurrent liabilities | 27 | 25 | |||
Total liabilities | [5] | 2,573 | 2,402 | ||
Atlantic City Electric Company [Member] | Variable Interest Entity, Primary Beneficiary [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Cash and cash equivalents | 0 | 0 | |||
Restricted cash | 4 | 6 | |||
Customer | 0 | 0 | |||
Other | 0 | 0 | |||
Materials and supplies | 0 | 0 | |||
Other current assets | 0 | 0 | |||
Total current assets | 4 | 6 | |||
Property, plant and equipment, net | 0 | 0 | |||
Nuclear decommissioning trust funds | 0 | 0 | |||
Other noncurrent assets | 19 | 23 | |||
Total noncurrent assets | 19 | 23 | |||
Total assets | 23 | 29 | |||
Long-term debt due within one year | 18 | 31 | |||
Accounts payable | 0 | 0 | |||
Accrued expenses | 1 | 1 | |||
Unamortized energy contract liabilities | 0 | 0 | |||
Other current liabilities | 0 | 0 | |||
Total current liabilities | 19 | 32 | |||
Long-term debt | 40 | 58 | |||
Asset retirement obligations | 0 | 0 | |||
Unamortized energy contract liabilities | 0 | ||||
Other noncurrent liabilities | 0 | 0 | |||
Total noncurrent liabilities | 40 | 58 | |||
Total liabilities | $ 59 | $ 90 | |||
[1] | Exelon’s consolidated assets include $9,667 million and $9,597 million at December 31, 2018 and 2017, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,548 million and $3,618 million at December 31, 2018 and 2017, respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 2–Variable Interest Entities for additional information. | ||||
[2] | Includes certain purchase accounting adjustments not pushed down to the ACE standalone entity. | ||||
[3] | Generation’s consolidated assets include $9,634 million and $9,556 million at December 31, 2018 and 2017, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,480 million and $3,516 million at December 31, 2018 and 2017, respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 2–Variable Interest Entities for additional information. | ||||
[4] | PHI’s consolidated total assets include $33 million and $41 million at December 31, 2018 and 2017, respectively, of PHI's consolidated VIE that can only be used to settle the liabilities of the VIE. PHI’s consolidated total liabilities include $69 million and $102 million at December 31, 2018 and 2017, respectively, of PHI's consolidated VIE for which the VIE creditors do not have recourse to PHI. See Note 2 - Variable Interest Entities for additional information. | ||||
[5] | ACE’s consolidated assets include $23 million and $29 million at December 31, 2018 and 2017, respectively, of ACE’s consolidated VIE that can only be used to settle the liabilities of the VIE. ACE’s consolidated liabilities include $59 million and $90 million at December 31, 2018 and 2017, respectively, of ACE’s consolidated VIE for which the VIE creditors do not have recourse to ACE. See Note 2 - Variable Interest Entities for additional information. |
Variable Interest Entities Va_4
Variable Interest Entities Variable Intereste Entities - Summary of Significant Unconsolidated VIEs (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Variable Interest Entity [Line Items] | |||
Total assets | [1] | $ 1,069 | $ 1,134 |
Total liabilities | [1] | 259 | 265 |
Exelon's ownership interest in VIE | [1] | 223 | 251 |
Other ownership interests in VIE | [1] | 587 | 618 |
Registrants maximum exposure to loss | 15 | ||
Carrying amount of equity method investments | |||
Variable Interest Entity [Line Items] | |||
Registrants maximum exposure to loss | 223 | 251 | |
Contract intangible asset | |||
Variable Interest Entity [Line Items] | |||
Registrants maximum exposure to loss | 7 | 8 | |
Net assets pledged for Zion Station decommissioning(b) | |||
Variable Interest Entity [Line Items] | |||
Registrants maximum exposure to loss | [2] | 0 | 2 |
Commercial Agreement Variable Interest Entities [Member] | |||
Variable Interest Entity [Line Items] | |||
Total assets | 597 | 625 | |
Total liabilities | 37 | 37 | |
Exelon's ownership interest in VIE | 0 | 0 | |
Other ownership interests in VIE | 560 | 588 | |
Commercial Agreement Variable Interest Entities [Member] | Carrying amount of equity method investments | |||
Variable Interest Entity [Line Items] | |||
Registrants maximum exposure to loss | 0 | 0 | |
Commercial Agreement Variable Interest Entities [Member] | Contract intangible asset | |||
Variable Interest Entity [Line Items] | |||
Registrants maximum exposure to loss | 7 | 8 | |
Commercial Agreement Variable Interest Entities [Member] | Net assets pledged for Zion Station decommissioning(b) | |||
Variable Interest Entity [Line Items] | |||
Registrants maximum exposure to loss | 0 | 2 | |
Equity Investment VIE [Member] | |||
Variable Interest Entity [Line Items] | |||
Total assets | 472 | 509 | |
Total liabilities | 222 | 228 | |
Exelon's ownership interest in VIE | 223 | 251 | |
Other ownership interests in VIE | 27 | 30 | |
Equity Investment VIE [Member] | Carrying amount of equity method investments | |||
Variable Interest Entity [Line Items] | |||
Registrants maximum exposure to loss | 223 | 251 | |
Equity Investment VIE [Member] | Contract intangible asset | |||
Variable Interest Entity [Line Items] | |||
Registrants maximum exposure to loss | 0 | 0 | |
Equity Investment VIE [Member] | Net assets pledged for Zion Station decommissioning(b) | |||
Variable Interest Entity [Line Items] | |||
Registrants maximum exposure to loss | 0 | 0 | |
Exelon Generation Co L L C [Member] | |||
Variable Interest Entity [Line Items] | |||
Registrants maximum exposure to loss | 13 | ||
Nuclear Decommissioning Asset Retirement Obligation [Member] | Exelon Generation Co L L C [Member] | |||
Variable Interest Entity [Line Items] | |||
Held-to-maturity Securities Pledged as Collateral | [3] | 9 | 39 |
Accounts Payable, Interest-bearing, Noncurrent | $ 9 | $ 37 | |
[1] | These items represent amounts on the unconsolidated VIE balance sheets, not in Exelon’s or Generation’s Consolidated Balance Sheets. These items are included to provide information regarding the relative size of the unconsolidated VIEs. | ||
[2] | These items represent amounts in Exelon’s and Generation’s Consolidated Balance Sheets related to the asset sale agreement with ZionSolutions, LLC. The net assets pledged for Zion Station decommissioning includes gross pledged assets of $9 million and $39 million as of December 31, 2018 and December 31, 2017, respectively; offset by payables to ZionSolutions LLC of $9 million and $37 million as of December 31, 2018 and December 31, 2017, respectively. These items are included to provide information regarding the relative size of the ZionSolutions, LLC unconsolidated VIE. | ||
[3] | (a)Included in Other current liabilities within Exelon's and Generation's Consolidated Balance Sheets. Excludes a liability recorded within Exelon’s and Generation’s Consolidated Balance Sheets related to the tax obligation on the unrealized gains and losses associated with the Zion Station NDT funds. The NDT funds will be utilized to satisfy the tax obligations as gains and losses are realized. |
Revenue Recognition Revenue R_3
Revenue Recognition Revenue Recognition - Narrative (Details) - USD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Capitalized Contract Cost [Line Items] | ||
Capitalized Contract Cost, Gross | $ 32 | $ 26 |
Capitalized Contract Cost, Amortization | 22 | 30 |
Exelon Generation Co L L C [Member] | ||
Capitalized Contract Cost [Line Items] | ||
Capitalized Contract Cost, Gross | 32 | 26 |
Capitalized Contract Cost, Amortization | $ 22 | $ 30 |
Revenue Recognition Contract As
Revenue Recognition Contract Assets and Liabilities (Details) - USD ($) $ in Millions | 12 Months Ended | |
Dec. 31, 2018 | Dec. 31, 2017 | |
Change in Contract with Customer, Asset and Liability [Abstract] | ||
Contract with Customer, Asset, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress | $ 50 | |
Contract with Customer, Asset, Reclassified to Receivable | (146) | |
Contract with Customer, Asset, Net, Current | 187 | $ 283 |
Contract with Customer, Liability, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress | 179 | |
Contract with Customer, Liability, Current | 27 | 35 |
Contract with Customer, Liability, Change in Timeframe, Performance Obligation Satisfied, Revenue Recognized | (187) | |
Exelon Generation Co L L C [Member] | ||
Change in Contract with Customer, Asset and Liability [Abstract] | ||
Contract with Customer, Asset, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress | 50 | |
Contract with Customer, Asset, Reclassified to Receivable | (146) | |
Contract with Customer, Asset, Net, Current | 187 | 283 |
Contract with Customer, Liability, Cumulative Catch-up Adjustment to Revenue, Change in Measure of Progress | 465 | |
Contract with Customer, Liability, Current | 42 | $ 35 |
Contract with Customer, Liability, Change in Timeframe, Performance Obligation Satisfied, Revenue Recognized | $ (458) |
Revenue Recognition Performance
Revenue Recognition Performance Obligations (Details) $ in Millions | Dec. 31, 2018USD ($) |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | $ 631 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | 329 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | 119 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | 47 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | 138 |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | 1,264 |
Exelon Generation Co L L C [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | 631 |
Exelon Generation Co L L C [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | 329 |
Exelon Generation Co L L C [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | 119 |
Exelon Generation Co L L C [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | 47 |
Exelon Generation Co L L C [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | 138 |
Exelon Generation Co L L C [Member] | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: (nil) | |
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items] | |
Revenue, Remaining Performance Obligation | $ 1,264 |
Regulatory Matters Regulatory M
Regulatory Matters Regulatory Matters- Narrative (Details) | Jan. 15, 2019USD ($) | Jan. 04, 2019USD ($) | Dec. 20, 2018USD ($) | Dec. 04, 2018USD ($) | Nov. 19, 2018USD ($) | Sep. 07, 2018USD ($) | Aug. 21, 2018USD ($) | Jul. 01, 2018USD ($) | Jun. 27, 2018USD ($) | Jun. 08, 2018USD ($) | Apr. 20, 2018USD ($) | [7] | Apr. 17, 2018USD ($) | [7] | Apr. 16, 2018USD ($) | Mar. 29, 2018USD ($) | Mar. 08, 2018USD ($) | [7] | Mar. 02, 2018USD ($) | Feb. 09, 2018USD ($) | Feb. 06, 2018USD ($) | Jan. 31, 2018USD ($) | Jan. 18, 2018USD ($) | Dec. 19, 2017USD ($) | Dec. 18, 2017USD ($) | Nov. 16, 2017USD ($) | Apr. 30, 2016USD ($) | Dec. 31, 2018USD ($) | Sep. 30, 2018USD ($) | Jun. 30, 2018USD ($) | Mar. 31, 2018USD ($) | Dec. 31, 2017USD ($) | Sep. 30, 2017USD ($) | Jun. 30, 2017USD ($) | Mar. 31, 2017USD ($) | Dec. 31, 2017USD ($) | Sep. 30, 2018USD ($) | Dec. 31, 2016USD ($) | Dec. 31, 2018USD ($) | Dec. 31, 2017USD ($) | Dec. 31, 2016USD ($) | Dec. 31, 2022USD ($) | Dec. 31, 2023USD ($) | Dec. 31, 2023USD ($) | Jul. 21, 2017USD ($) | Aug. 31, 2010USD ($) | ||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Other Commitment | $ 127,000,000 | $ 127,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 9,459,000,000 | $ 9,288,000,000 | $ 9,288,000,000 | 9,459,000,000 | $ 9,288,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Amortization Rate Stabilization Deferral | 14,000,000 | (10,000,000) | $ 76,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 35,000,000 | 35,000,000 | 35,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Current | 644,000,000 | 523,000,000 | 523,000,000 | 644,000,000 | 523,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory liabilities, noncurrent | 9,559,000,000 | 9,865,000,000 | 9,865,000,000 | 9,559,000,000 | 9,865,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Revenues | 8,814,000,000 | $ 9,403,000,000 | $ 8,076,000,000 | $ 9,693,000,000 | 8,384,000,000 | $ 8,768,000,000 | $ 7,665,000,000 | $ 8,747,000,000 | 35,985,000,000 | 33,565,000,000 | 31,366,000,000 | |||||||||||||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 7,000,000 | [1] | 16,000,000 | [1] | 143,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liabilities | 10,203,000,000 | 10,388,000,000 | 10,388,000,000 | 10,203,000,000 | 10,388,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 3,800,000,000 | 3,532,000,000 | 3,532,000,000 | 3,800,000,000 | 3,532,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | 7,594,000,000 | 7,584,000,000 | 8,553,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
PJM Transmission Rate Design Settlement [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 176,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
DC PLUG charge | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 159,000,000 | 190,000,000 | 190,000,000 | 159,000,000 | 190,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Fair value of long-term debt | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 758,000,000 | 758,000,000 | 758,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Advanced Metering Infrastructure Legacy Meter Costs [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 328,000,000 | 223,000,000 | 223,000,000 | 328,000,000 | 223,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Electric Energy and Natural Gas Costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 193,000,000 | 47,000,000 | 47,000,000 | 193,000,000 | 47,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Merger integration costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 42,000,000 | 45,000,000 | 45,000,000 | 42,000,000 | 45,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Energy efficiency and demand response programs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 545,000,000 | 596,000,000 | 596,000,000 | 545,000,000 | 596,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Revenues | 4,670,000,000 | 4,829,000,000 | 3,785,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Amortization Rate Stabilization Deferral | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
Revenues | 5,069,000,000 | 5,278,000,000 | 4,579,000,000 | 5,512,000,000 | 4,657,000,000 | 4,750,000,000 | 4,216,000,000 | 4,878,000,000 | 20,437,000,000 | 18,500,000,000 | 17,757,000,000 | |||||||||||||||||||||||||||||||||||||||
Purchase Obligation | $ 235,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 5,000,000 | [1] | 22,000,000 | [1] | 37,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 1,847,000,000 | 1,773,000,000 | 1,773,000,000 | 1,847,000,000 | 1,773,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | 2,242,000,000 | 2,259,000,000 | 3,078,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | Conowingo [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
License Costs | 37,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | One-Time Revenue Adjustment [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Revenues | $ 101,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | PJM Transmission Rate Design Settlement [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | [2] | 41,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | Minimum [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Purchase Obligation | 3,000,000 | 3,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | Maximum [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Purchase Obligation | 7,000,000 | 7,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | Zero emission credit costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Revenues | 438,000,000 | $ 311,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Other Revenue, Net | 150,000,000 | 373,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Commonwealth Edison Co [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
SocialCarbonCost | 16.50 | |||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [3] | $ (44,000,000) | ||||||||||||||||||||||||||||||||||||||||||||||||
Cap on Equity Component of Rate of Return on Common Equity in Federal Energy Regulatory Committee Complaint | 55.00% | |||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [3],[4] | $ (26,000,000) | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [3],[5] | 11.50% | ||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 1,279,000,000 | 1,279,000,000 | $ 1,279,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Amortization Rate Stabilization Deferral | $ 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 3,000,000 | 3,000,000 | 3,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Current | 293,000,000 | 249,000,000 | 249,000,000 | 293,000,000 | 249,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory liabilities, noncurrent | 6,050,000,000 | 6,328,000,000 | 6,328,000,000 | 6,050,000,000 | 6,328,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Revenues | 1,373,000,000 | 1,598,000,000 | 1,398,000,000 | 1,512,000,000 | 1,309,000,000 | 1,571,000,000 | 1,357,000,000 | 1,298,000,000 | 5,882,000,000 | 5,536,000,000 | 5,254,000,000 | |||||||||||||||||||||||||||||||||||||||
Purchase Obligation | $ 170,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 0 | [1],[6] | 1,000,000 | [1],[6] | (6,000,000) | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liabilities | 6,343,000,000 | 6,577,000,000 | 6,577,000,000 | 6,343,000,000 | 6,577,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Prior Year Revenue Adjustment | [3] | 18,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 201,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 607,000,000 | 568,000,000 | 568,000,000 | 607,000,000 | 568,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | 2,126,000,000 | 2,250,000,000 | 2,734,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Commonwealth Edison Co [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | (58,000,000) | |||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | 34,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [7] | $ (24,000,000) | $ (23,000,000) | |||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Equity Capital Structure, Percentage | 8.69% | |||||||||||||||||||||||||||||||||||||||||||||||||
Commonwealth Edison Co [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | 69,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Commonwealth Edison Co [Member] | PJM Transmission Rate Design Settlement [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||
Commonwealth Edison Co [Member] | DC PLUG charge | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
Commonwealth Edison Co [Member] | Fair value of long-term debt | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
Commonwealth Edison Co [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 136,000,000 | 155,000,000 | 155,000,000 | 136,000,000 | 155,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Commonwealth Edison Co [Member] | Electric Energy and Natural Gas Costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
Commonwealth Edison Co [Member] | Merger integration costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
Commonwealth Edison Co [Member] | Energy efficiency and demand response programs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | 22,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 410,000,000 | 410,000,000 | 410,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Amortization Rate Stabilization Deferral | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Current | 175,000,000 | 141,000,000 | 141,000,000 | 175,000,000 | 141,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory liabilities, noncurrent | 421,000,000 | 549,000,000 | 549,000,000 | 421,000,000 | 549,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Revenues | 765,000,000 | 757,000,000 | 653,000,000 | 866,000,000 | 729,000,000 | 715,000,000 | 630,000,000 | 796,000,000 | 3,038,000,000 | 2,870,000,000 | 2,994,000,000 | |||||||||||||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 1,000,000 | [1] | 4,000,000 | [1] | 5,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liabilities | 596,000,000 | 690,000,000 | 690,000,000 | $ 596,000,000 | 690,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Equity Capital Structure, Percentage | 11.00% | |||||||||||||||||||||||||||||||||||||||||||||||||
Prior Year Revenue Adjustment | $ 6,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 71,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 370,000,000 | 370,000,000 | 370,000,000 | $ 370,000,000 | 370,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | 849,000,000 | 732,000,000 | 686,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [7] | $ 82,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [7] | $ 25,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | Gas Distribution [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 4,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | PJM Transmission Rate Design Settlement [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | DC PLUG charge | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | Fair value of long-term debt | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 36,000,000 | 36,000,000 | 36,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | Electric Energy and Natural Gas Costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 1,000,000 | 1,000,000 | 1,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | Merger integration costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
PECO Energy Co [Member] | Energy efficiency and demand response programs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 1,000,000 | 1,000,000 | 1,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [3] | 10,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [3],[4],[8] | $ 26,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 10.50% | |||||||||||||||||||||||||||||||||||||||||||||||||
Proposed Capital Expenditure | $ 12,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 571,000,000 | 571,000,000 | 571,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Amortization Rate Stabilization Deferral | 0 | 7,000,000 | 81,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Estimated number of smart meters to be installed | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||
Total smart grid smart meter investment grant awarded | $ 480,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Doe Reimbursements | $ 200,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 5,000,000 | 5,000,000 | 5,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Current | 77,000,000 | 62,000,000 | 62,000,000 | 77,000,000 | 62,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory liabilities, noncurrent | 1,192,000,000 | 1,101,000,000 | 1,101,000,000 | 1,192,000,000 | 1,101,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Revenues | 799,000,000 | 731,000,000 | 662,000,000 | 977,000,000 | 813,000,000 | 738,000,000 | 674,000,000 | 951,000,000 | 3,169,000,000 | 3,176,000,000 | 3,233,000,000 | |||||||||||||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 1,000,000 | [1],[6] | 4,000,000 | [1],[6] | (1,000,000) | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liabilities | 1,269,000,000 | 1,163,000,000 | 1,163,000,000 | 1,269,000,000 | 1,163,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Prior Year Revenue Adjustment | [3] | 4,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 295,000,000 | 265,000,000 | 265,000,000 | 295,000,000 | 265,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | 959,000,000 | 882,000,000 | 934,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Subsequent Event [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 200,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Proposed Capital Expenditure | $ 732,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 72,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Gas Distribution [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 61,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 43,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 31,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | 18,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | PJM Transmission Rate Design Settlement [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 51,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Difference between Carrying Value and Fair Value [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 133,000,000 | 139,000,000 | 139,000,000 | 133,000,000 | 139,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | DC PLUG charge | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Fair value of long-term debt | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | AMI programs - Deployment Costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 52,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 48,000,000 | 53,000,000 | 56,000,000 | 53,000,000 | 48,000,000 | 53,000,000 | ||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Electric Energy and Natural Gas Costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 16,000,000 | 16,000,000 | 16,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Merger integration costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 6,000,000 | 6,000,000 | 6,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Energy efficiency and demand response programs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 285,000,000 | 285,000,000 | 285,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Other Commitment | 444,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 3,047,000,000 | 3,047,000,000 | 3,047,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Amortization Rate Stabilization Deferral | 14,000,000 | (17,000,000) | ||||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 27,000,000 | 27,000,000 | 27,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Current | 84,000,000 | 56,000,000 | 56,000,000 | 84,000,000 | 56,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory liabilities, noncurrent | 1,864,000,000 | 1,872,000,000 | 1,872,000,000 | 1,864,000,000 | 1,872,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Revenues | 1,117,000,000 | 1,361,000,000 | 1,076,000,000 | 1,251,000,000 | 1,121,000,000 | 1,310,000,000 | 1,074,000,000 | 1,175,000,000 | 4,805,000,000 | 4,679,000,000 | ||||||||||||||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 0 | [1],[6] | (6,000,000) | [1],[6] | 28,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liabilities | 1,948,000,000 | 1,928,000,000 | 1,928,000,000 | 1,948,000,000 | 1,928,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Impairment of Long-Lived Assets to be Disposed of | 25,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 496,000,000 | 348,000,000 | 348,000,000 | 496,000,000 | 348,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | 1,375,000,000 | 1,396,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | PJM Transmission Rate Design Settlement [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 84,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Successor [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Amortization Rate Stabilization Deferral | $ (5,000,000) | |||||||||||||||||||||||||||||||||||||||||||||||||
Revenues | 3,643,000,000 | 4,679,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | [6] | 69,000,000 | 0 | (18,000,000) | [1] | |||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | $ 1,008,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | DC PLUG charge | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 159,000,000 | 190,000,000 | 190,000,000 | 159,000,000 | 190,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Fair value of long-term debt | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 569,000,000 | 619,000,000 | 619,000,000 | 569,000,000 | 619,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 120,000,000 | 134,000,000 | 134,000,000 | 120,000,000 | 134,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Electric Energy and Natural Gas Costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 93,000,000 | 30,000,000 | 30,000,000 | 93,000,000 | 30,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Merger integration costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 39,000,000 | 39,000,000 | 39,000,000 | 39,000,000 | 39,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Energy efficiency and demand response programs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 255,000,000 | 310,000,000 | 310,000,000 | 255,000,000 | 310,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Other Commitment | 320,000,000 | 320,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 6,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [4] | $ 8,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [5] | 10.50% | ||||||||||||||||||||||||||||||||||||||||||||||||
Projected Capital Expenditures | 500,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 891,000,000 | 891,000,000 | 891,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Amortization Rate Stabilization Deferral | $ 14,000,000 | (17,000,000) | (12,000,000) | |||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 14,000,000 | 14,000,000 | 14,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Current | 7,000,000 | 3,000,000 | 3,000,000 | 7,000,000 | 3,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory liabilities, noncurrent | 822,000,000 | 829,000,000 | 829,000,000 | 822,000,000 | 829,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Revenues | 531,000,000 | 628,000,000 | 523,000,000 | 557,000,000 | 510,000,000 | 604,000,000 | 514,000,000 | 530,000,000 | 2,239,000,000 | 2,158,000,000 | 2,186,000,000 | |||||||||||||||||||||||||||||||||||||||
Regulatory Liabilities | 829,000,000 | 832,000,000 | 832,000,000 | 829,000,000 | 832,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Alternative Net Capital Requirement | 250,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Capital ProjectFundedByBonds | 187,500,000 | 30,000,000 | $ 127,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
CapitalProjectFundedByAgency | 62,500,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Prior Year Revenue Adjustment | 2,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 214,000,000 | 139,000,000 | 139,000,000 | 214,000,000 | 139,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | 656,000,000 | 628,000,000 | 586,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 30,000,000 | $ 66,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 4,000,000 | $ (15,000,000) | $ (24,000,000) | $ 3,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 39,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | 13,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | PJM Transmission Rate Design Settlement [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 84,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | DC PLUG charge | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 159,000,000 | 190,000,000 | 190,000,000 | 159,000,000 | 190,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | MergerIntegrationCostsToBeRecoveredInDCServiceTerritory [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 9,000,000 | 9,000,000 | 9,000,000 | 9,000,000 | 9,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Fair value of long-term debt | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | MergerIntegrationCostsToBeRecoveredInMarylandServiceTerritory [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 9,000,000 | 11,000,000 | 11,000,000 | 9,000,000 | 11,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 90,000,000 | 100,000,000 | 100,000,000 | 90,000,000 | 100,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Electric Energy and Natural Gas Costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 84,000,000 | 8,000,000 | 8,000,000 | 84,000,000 | 8,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Merger integration costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 18,000,000 | 20,000,000 | 20,000,000 | 18,000,000 | 20,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Energy efficiency and demand response programs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 188,000,000 | 229,000,000 | 229,000,000 | 188,000,000 | 229,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Other Commitment | 120,000,000 | 120,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 14,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [4] | $ 27,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [5] | 10.50% | ||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 314,000,000 | 314,000,000 | 314,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Amortization Rate Stabilization Deferral | $ 0 | 0 | 2,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 6,000,000 | 6,000,000 | 6,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Current | 59,000,000 | 42,000,000 | 42,000,000 | 59,000,000 | 42,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory liabilities, noncurrent | 606,000,000 | 593,000,000 | 593,000,000 | 606,000,000 | 593,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Revenues | 331,000,000 | 328,000,000 | 289,000,000 | 384,000,000 | 330,000,000 | 327,000,000 | 282,000,000 | 362,000,000 | 1,332,000,000 | 1,300,000,000 | 1,277,000,000 | |||||||||||||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 0 | [1],[6] | (7,000,000) | [1],[6] | 20,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liabilities | 665,000,000 | 635,000,000 | 635,000,000 | 665,000,000 | 635,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Prior Year Revenue Adjustment | 13,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 111,000,000 | 82,000,000 | 82,000,000 | 111,000,000 | 82,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | 364,000,000 | 428,000,000 | 349,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [7] | $ (7,000,000) | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 13,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 12,000,000 | [7] | $ 19,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.50% | |||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | 19,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Gas Distribution [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [7] | $ (4,000,000) | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [7] | 4,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 7,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | 12,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | PJM Transmission Rate Design Settlement [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 0 | |||||||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | DC PLUG charge | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Fair value of long-term debt | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 30,000,000 | 34,000,000 | 34,000,000 | 30,000,000 | 34,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Electric Energy and Natural Gas Costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 7,000,000 | 7,000,000 | 0 | 7,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Merger integration costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 11,000,000 | 10,000,000 | 10,000,000 | 11,000,000 | 10,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Energy efficiency and demand response programs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 67,000,000 | 81,000,000 | 81,000,000 | 67,000,000 | 81,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Other Commitment | 89,000,000 | 89,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 40,000,000 | 4,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [4] | $ 0 | ||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [5] | 10.50% | ||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 430,000,000 | 430,000,000 | 430,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Amortization Rate Stabilization Deferral | $ 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 7,000,000 | 7,000,000 | 7,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liability, Current | 18,000,000 | 11,000,000 | 11,000,000 | 18,000,000 | 11,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory liabilities, noncurrent | 402,000,000 | 411,000,000 | 411,000,000 | 402,000,000 | 411,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Revenues | 254,000,000 | 406,000,000 | 265,000,000 | $ 310,000,000 | 271,000,000 | $ 370,000,000 | $ 270,000,000 | $ 275,000,000 | 1,236,000,000 | 1,186,000,000 | 1,257,000,000 | |||||||||||||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 0 | [1],[6] | (6,000,000) | [1],[6] | 19,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Regulatory Liabilities | 420,000,000 | 422,000,000 | 422,000,000 | 420,000,000 | 422,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Prior Year Revenue Adjustment | (4,000,000) | |||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 23,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | 154,000,000 | 118,000,000 | 118,000,000 | 154,000,000 | 118,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | 335,000,000 | 312,000,000 | $ 311,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Subsequent Event [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Payments to Acquire Property, Plant, and Equipment | $ 338,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [9] | $ 122,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | 11,000,000 | |||||||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | PJM Transmission Rate Design Settlement [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Accounts Payable, Current | $ 0 | |||||||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | DC PLUG charge | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Fair value of long-term debt | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | 0 | 0 | 0 | 0 | |||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Electric Energy and Natural Gas Costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 9,000,000 | 15,000,000 | 15,000,000 | 9,000,000 | 15,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Merger integration costs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 10,000,000 | 9,000,000 | 9,000,000 | 10,000,000 | 9,000,000 | |||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Energy efficiency and demand response programs | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Assets | 0 | $ 0 | $ 0 | 0 | $ 0 | |||||||||||||||||||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Other Commitment | $ 111,000,000 | $ 111,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
One-Time Revenue Adjustment [Member] | Maximum [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 76,000,000 | 76,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
One-Time Revenue Adjustment [Member] | Commonwealth Edison Co [Member] | Maximum [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 51,000,000 | 51,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
One-Time Revenue Adjustment [Member] | Baltimore Gas and Electric Company [Member] | Maximum [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 15,000,000 | 15,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
One-Time Revenue Adjustment [Member] | Pepco Holdings LLC [Member] | Maximum [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 10,000,000 | 10,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
One-Time Revenue Adjustment [Member] | Potomac Electric Power Company [Member] | Maximum [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 3,000,000 | 3,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
One-Time Revenue Adjustment [Member] | Delmarva Power & Light Company [Member] | Maximum [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | 5,000,000 | 5,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
One-Time Revenue Adjustment [Member] | Atlantic City Electric Company [Member] | Maximum [Member] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Regulatory Matters Additional Narrative Information [Line Items] | ||||||||||||||||||||||||||||||||||||||||||||||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | $ 2,000,000 | $ 2,000,000 | ||||||||||||||||||||||||||||||||||||||||||||||||
[1] | The costs incurred are classified primarily within Operating and maintenance expense in the Registrants’ respective Consolidated Statements of Operations and Comprehensive Income, with the exception of the financing costs, which are included within Interest expense. Costs do not include merger commitments discussed above. | |||||||||||||||||||||||||||||||||||||||||||||||||
[2] | Does not include an offsetting receivable from New Jersey Utilities of $16 million as of December 31, 2018. | |||||||||||||||||||||||||||||||||||||||||||||||||
[3] | The time period for any formal challenges to the annual transmission formula rate update filings expired with no formal challenges submitted. | |||||||||||||||||||||||||||||||||||||||||||||||||
[4] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246MzY0MUFFQzNGNTE3Mzk3OTI2RjIxNTRFRUQyNkYyMzMM} | |||||||||||||||||||||||||||||||||||||||||||||||||
[5] | As part of the FERC-approved settlement of ComEd’s 2007 transmission rate case, the rate of return on common equity is 11.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO, and the common equity component of the ratio used to calculate the weighted average debt and equity return for the transmission formula rate is currently capped at 55%. As part of the FERC-approved settlement of the ROE complaint against BGE, Pepco, DPL and ACE, the rate of return on common equity is 10.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO. | |||||||||||||||||||||||||||||||||||||||||||||||||
[6] | (b)For the year ended December 31, 2017, includes deferrals of previously incurred integration costs as regulatory assets of $24 million, $8 million, $8 million, and $8 million at PHI, Pepco, DPL and ACE, respectively. For the year ended December 31, 2016, includes deferrals of previously incurred integration costs as regulatory assets of $8 million, $6 million, $11 million and $4 million at ComEd, BGE, Pepco and DPL, respectively. For the Successor period March 24, 2016 to December 31, 2016, includes deferrals of previously incurred integration costs as regulatory assets of $16 million at PHI. See Note 4 - Regulatory Matters for additional information. | |||||||||||||||||||||||||||||||||||||||||||||||||
[7] | Includes the annual ongoing TCJA tax savings further discussed below. | |||||||||||||||||||||||||||||||||||||||||||||||||
[8] | BGE's transmission revenue requirement includes a FERC approved dedicated facilities charge of $12 million to recover the costs of providing transmission service to specifically designated load by BGE. | |||||||||||||||||||||||||||||||||||||||||||||||||
[9] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246NUYyM0EwMDI1MDhGQUUyMUZEMzExNTNGOUY0NjExNDUM} |
Regulatory Matters Regulatory_2
Regulatory Matters Regulatory Matters - Annual Electric Distribution/Transmission Filings (Details) - USD ($) $ in Millions | Jan. 15, 2019 | Dec. 04, 2018 | Nov. 19, 2018 | Sep. 07, 2018 | Aug. 21, 2018 | Jun. 27, 2018 | May 31, 2018 | Apr. 20, 2018 | [4] | Apr. 17, 2018 | Apr. 16, 2018 | Mar. 08, 2018 | [4] | Mar. 02, 2018 | Feb. 09, 2018 | Feb. 06, 2018 | Jan. 31, 2018 | Jan. 18, 2018 | Dec. 19, 2017 | Dec. 18, 2017 | Nov. 16, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | |||
Commonwealth Edison Co [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [1] | $ (44) | ||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 201 | |||||||||||||||||||||||||
Prior Year Revenue Adjustment | [1] | $ 18 | ||||||||||||||||||||||||
Cap on Equity Component of Rate of Return on Common Equity in Federal Energy Regulatory Committee Complaint | 55.00% | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [1],[2] | $ (26) | ||||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | [1] | 8.32% | ||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [1],[3] | 11.50% | ||||||||||||||||||||||||
Commonwealth Edison Co [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ (58) | |||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 34 | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [4] | $ (24) | $ (23) | |||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 6.52% | |||||||||||||||||||||||||
Public Utilities, Requested Equity Capital Structure, Percentage | 8.69% | |||||||||||||||||||||||||
Commonwealth Edison Co [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 69 | |||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [1] | 10 | ||||||||||||||||||||||||
Prior Year Revenue Adjustment | [1] | 4 | ||||||||||||||||||||||||
Proposed Capital Expenditure | 12 | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [1],[2],[5] | $ 26 | ||||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | [1] | 7.61% | ||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 10.50% | |||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 72 | |||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 18 | |||||||||||||||||||||||||
Potomac Electric Power Company [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 6 | |||||||||||||||||||||||||
Prior Year Revenue Adjustment | 2 | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [2] | $ 8 | ||||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 7.82% | |||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [3] | 10.50% | ||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 30 | $ 66 | ||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 39 | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 4 | $ (15) | $ (24) | [4] | $ 3 | |||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 10.30% | 9.50% | 9.525% | |||||||||||||||||||||||
Potomac Electric Power Company [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 13 | |||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | 14 | |||||||||||||||||||||||||
Prior Year Revenue Adjustment | 13 | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [2] | $ 27 | ||||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 7.29% | |||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [3] | 10.50% | ||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [4] | $ (7) | ||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 19 | |||||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 13 | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 12 | [4] | $ 19 | |||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.50% | |||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 9.70% | |||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 12 | |||||||||||||||||||||||||
Atlantic City Electric Company [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 40 | 4 | ||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 23 | |||||||||||||||||||||||||
Prior Year Revenue Adjustment | (4) | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [2] | $ 0 | ||||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 8.02% | |||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [3] | 10.50% | ||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Electric Distribution [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [6] | $ 122 | ||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 10.10% | |||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Electric Transmission [Member] | ||||||||||||||||||||||||||
Public Utilities, General Disclosures [Line Items] | ||||||||||||||||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 11 | |||||||||||||||||||||||||
[1] | The time period for any formal challenges to the annual transmission formula rate update filings expired with no formal challenges submitted. | |||||||||||||||||||||||||
[2] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246MzY0MUFFQzNGNTE3Mzk3OTI2RjIxNTRFRUQyNkYyMzMM} | |||||||||||||||||||||||||
[3] | As part of the FERC-approved settlement of ComEd’s 2007 transmission rate case, the rate of return on common equity is 11.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO, and the common equity component of the ratio used to calculate the weighted average debt and equity return for the transmission formula rate is currently capped at 55%. As part of the FERC-approved settlement of the ROE complaint against BGE, Pepco, DPL and ACE, the rate of return on common equity is 10.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO. | |||||||||||||||||||||||||
[4] | Includes the annual ongoing TCJA tax savings further discussed below. | |||||||||||||||||||||||||
[5] | BGE's transmission revenue requirement includes a FERC approved dedicated facilities charge of $12 million to recover the costs of providing transmission service to specifically designated load by BGE. | |||||||||||||||||||||||||
[6] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246NUYyM0EwMDI1MDhGQUUyMUZEMzExNTNGOUY0NjExNDUM} |
Regulatory Matters Regulatory_3
Regulatory Matters Regulatory Matters - Schedule of Regulatory Asset Impairment (Details) $ in Millions | Dec. 31, 2017USD ($) |
Amount of Impairment to Carrying Amount of Regulatory Assets | $ 35 |
Commonwealth Edison Co [Member] | |
Amount of Impairment to Carrying Amount of Regulatory Assets | 3 |
Baltimore Gas and Electric Company [Member] | |
Amount of Impairment to Carrying Amount of Regulatory Assets | 5 |
Pepco Holdings LLC [Member] | |
Amount of Impairment to Carrying Amount of Regulatory Assets | 27 |
Potomac Electric Power Company [Member] | |
Amount of Impairment to Carrying Amount of Regulatory Assets | 14 |
Delmarva Power & Light Company [Member] | |
Amount of Impairment to Carrying Amount of Regulatory Assets | 6 |
Atlantic City Electric Company [Member] | |
Amount of Impairment to Carrying Amount of Regulatory Assets | $ 7 |
Regulatory Matters Regulatory_4
Regulatory Matters Regulatory Matters - Estimated Commitments related to PJM Agreements (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Jun. 30, 2018 | Dec. 31, 2017 | Mar. 31, 2017 | |
Other Commitments [Line Items] | |||||
Other Receivables | $ 1,256 | $ 1,132 | |||
Total | 127 | ||||
Accounts Payable, Current | 3,800 | 3,532 | |||
Regulatory Assets | 9,459 | 9,288 | |||
Regulatory Liabilities | 10,203 | 10,388 | |||
Exelon Generation Co L L C [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 562 | 321 | |||
Accounts Payable, Current | 1,847 | 1,773 | |||
Commonwealth Edison Co [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 320 | 266 | |||
Accounts Payable, Current | 607 | 568 | |||
Regulatory Assets | 1,279 | ||||
Regulatory Liabilities | 6,343 | 6,577 | |||
PECO Energy Co [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 151 | 105 | |||
Accounts Payable, Current | 370 | 370 | |||
Regulatory Assets | 410 | ||||
Regulatory Liabilities | 596 | 690 | |||
Baltimore Gas and Electric Company [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 90 | 94 | |||
Accounts Payable, Current | 295 | 265 | |||
Regulatory Assets | 571 | ||||
Regulatory Liabilities | 1,269 | 1,163 | |||
Potomac Electric Power Company [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 81 | 87 | |||
Accounts Payable, Current | 214 | 139 | |||
Regulatory Assets | 891 | ||||
Regulatory Liabilities | 829 | 832 | |||
Delmarva Power & Light Company [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 46 | 38 | |||
Accounts Payable, Current | 111 | 82 | |||
Regulatory Assets | 314 | ||||
Regulatory Liabilities | 665 | 635 | |||
Atlantic City Electric Company [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 55 | 56 | |||
Accounts Payable, Current | 154 | 118 | |||
Regulatory Assets | 430 | ||||
Regulatory Liabilities | 420 | 422 | |||
Pepco Holdings LLC [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 177 | 206 | |||
Total | $ 444 | ||||
Accounts Payable, Current | 496 | 348 | |||
Regulatory Assets | 3,047 | ||||
Regulatory Liabilities | 1,948 | $ 1,928 | |||
PJM Transmission Rate Design Settlement [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | $ 220 | ||||
Accounts Payable, Current | 176 | ||||
PJM Transmission Rate Design Settlement [Member] | Exelon Generation Co L L C [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | [1] | 0 | |||
Accounts Payable, Current | [1] | 41 | |||
Accounts Receivable, Gross, Current | $ 16 | ||||
PJM Transmission Rate Design Settlement [Member] | Commonwealth Edison Co [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 122 | ||||
Accounts Payable, Current | 0 | ||||
PJM Transmission Rate Design Settlement [Member] | PECO Energy Co [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 85 | ||||
Accounts Payable, Current | 0 | ||||
PJM Transmission Rate Design Settlement [Member] | Baltimore Gas and Electric Company [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 0 | ||||
Accounts Payable, Current | 51 | ||||
PJM Transmission Rate Design Settlement [Member] | Potomac Electric Power Company [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 0 | ||||
Accounts Payable, Current | 84 | ||||
PJM Transmission Rate Design Settlement [Member] | Delmarva Power & Light Company [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 10 | ||||
Accounts Payable, Current | 0 | ||||
PJM Transmission Rate Design Settlement [Member] | Atlantic City Electric Company [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 3 | ||||
Accounts Payable, Current | 0 | ||||
PJM Transmission Rate Design Settlement [Member] | Pepco Holdings LLC [Member] | |||||
Other Commitments [Line Items] | |||||
Other Receivables | 13 | ||||
Accounts Payable, Current | 84 | ||||
PJM Transmission Rate Design Settlement [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Assets | 136 | ||||
PJM Transmission Rate Design Settlement [Member] | Exelon Generation Co L L C [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Assets | [1] | 0 | |||
PJM Transmission Rate Design Settlement [Member] | Commonwealth Edison Co [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Assets | 0 | ||||
PJM Transmission Rate Design Settlement [Member] | PECO Energy Co [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Assets | 0 | ||||
PJM Transmission Rate Design Settlement [Member] | Baltimore Gas and Electric Company [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Assets | 51 | ||||
PJM Transmission Rate Design Settlement [Member] | Potomac Electric Power Company [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Assets | 84 | ||||
PJM Transmission Rate Design Settlement [Member] | Delmarva Power & Light Company [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Assets | 0 | ||||
PJM Transmission Rate Design Settlement [Member] | Atlantic City Electric Company [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Assets | 1 | ||||
PJM Transmission Rate Design Settlement [Member] | Pepco Holdings LLC [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Assets | 85 | ||||
PJM Transmission Rate Design Settlement [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Liabilities | 221 | ||||
PJM Transmission Rate Design Settlement [Member] | Exelon Generation Co L L C [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Liabilities | [1] | 0 | |||
PJM Transmission Rate Design Settlement [Member] | Commonwealth Edison Co [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Liabilities | 122 | ||||
PJM Transmission Rate Design Settlement [Member] | PECO Energy Co [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Liabilities | 85 | ||||
PJM Transmission Rate Design Settlement [Member] | Baltimore Gas and Electric Company [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Liabilities | 0 | ||||
PJM Transmission Rate Design Settlement [Member] | Potomac Electric Power Company [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Liabilities | 0 | ||||
PJM Transmission Rate Design Settlement [Member] | Delmarva Power & Light Company [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Liabilities | 10 | ||||
PJM Transmission Rate Design Settlement [Member] | Atlantic City Electric Company [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Liabilities | 4 | ||||
PJM Transmission Rate Design Settlement [Member] | Pepco Holdings LLC [Member] | |||||
Other Commitments [Line Items] | |||||
Regulatory Liabilities | $ 14 | ||||
[1] | Does not include an offsetting receivable from New Jersey Utilities of $16 million as of December 31, 2018. |
Regulatory Matters Regulatory_5
Regulatory Matters Regulatory Matters - Schedule of Regulatory Assets (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | Jun. 30, 2017 |
Regulatory Assets [Line Items] | |||
Regulatory Assets | $ 9,459 | $ 9,288 | |
Current regulatory assets | 1,222 | 1,267 | |
Noncurrent regulatory assets | 8,237 | 8,021 | |
Pension and Other Postretirement Plans Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 2,455 | ||
Pension and Post Retirement Plan Merger Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 1,266 | 1,393 | |
Deferred income taxes | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 414 | 306 | |
Advanced Metering Infrastructure Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 202 | 385 | |
Advanced Metering Infrastructure Legacy Meter Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 328 | 223 | |
Advanced Metering Infrastructure Incremental Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 32 | 32 | |
Electric Distribution Formula Rate Annual Reconciliations [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 158 | 186 | |
Electric Distribution Formula Rate One-time Events [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 81 | 58 | |
Energy efficiency costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 472 | 166 | |
Fair value of long-term debt | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 758 | ||
Fair value of PHI's unamortized energy contracts | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 561 | 750 | |
Asset retirement obligations | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 118 | 109 | |
MGP remediation costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 326 | 295 | |
Renewable Energy Program [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 249 | 258 | |
Electric Energy and Natural Gas Costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 193 | 47 | |
Under Recovered Transmission Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 41 | 35 | |
Energy efficiency and demand response programs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 545 | 596 | |
Merger integration costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 42 | 45 | |
Under-recovered revenue decoupling | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 59 | 55 | |
Securitized stranded costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 50 | 79 | |
Removal costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 564 | 529 | |
DC PLUG charge | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 159 | 190 | |
Storm Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 41 | 27 | |
Other | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 303 | 311 | |
Commonwealth Edison Co [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 1,279 | ||
Current regulatory assets | 293 | 225 | |
Noncurrent regulatory assets | 1,307 | 1,054 | |
Commonwealth Edison Co [Member] | Pension and Other Postretirement Plans Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | Pension and Post Retirement Plan Merger Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Commonwealth Edison Co [Member] | Deferred income taxes | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | Advanced Metering Infrastructure Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Commonwealth Edison Co [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 136 | 155 | |
Commonwealth Edison Co [Member] | Advanced Metering Infrastructure Incremental Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Commonwealth Edison Co [Member] | Electric Distribution Formula Rate Annual Reconciliations [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 158 | 186 | |
Commonwealth Edison Co [Member] | Electric Distribution Formula Rate One-time Events [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 81 | 58 | |
Commonwealth Edison Co [Member] | Energy efficiency costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 166 | ||
Commonwealth Edison Co [Member] | Fair value of long-term debt | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | Fair value of PHI's unamortized energy contracts | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | Asset retirement obligations | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 79 | 73 | |
Commonwealth Edison Co [Member] | MGP remediation costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 309 | 273 | |
Commonwealth Edison Co [Member] | Renewable Energy Program [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 256 | ||
Commonwealth Edison Co [Member] | Electric Energy and Natural Gas Costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | Under Recovered Transmission Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 6 | 6 | |
Commonwealth Edison Co [Member] | Energy efficiency and demand response programs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | Merger integration costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | Under-recovered revenue decoupling | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | Securitized stranded costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | Removal costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | DC PLUG charge | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Commonwealth Edison Co [Member] | Storm Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Commonwealth Edison Co [Member] | Other | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 106 | ||
PECO Energy Co [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 410 | ||
Current regulatory assets | 81 | 29 | |
Noncurrent regulatory assets | 460 | 381 | |
PECO Energy Co [Member] | Pension and Other Postretirement Plans Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | Pension and Post Retirement Plan Merger Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
PECO Energy Co [Member] | Deferred income taxes | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 297 | ||
PECO Energy Co [Member] | Advanced Metering Infrastructure Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
PECO Energy Co [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 36 | ||
PECO Energy Co [Member] | Advanced Metering Infrastructure Incremental Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
PECO Energy Co [Member] | Electric Distribution Formula Rate Annual Reconciliations [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | Electric Distribution Formula Rate One-time Events [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
PECO Energy Co [Member] | Energy efficiency costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | Fair value of long-term debt | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | Fair value of PHI's unamortized energy contracts | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
PECO Energy Co [Member] | Asset retirement obligations | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 22 | ||
PECO Energy Co [Member] | MGP remediation costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 22 | ||
PECO Energy Co [Member] | Renewable Energy Program [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | Electric Energy and Natural Gas Costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 1 | ||
PECO Energy Co [Member] | Under Recovered Transmission Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | Energy efficiency and demand response programs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 1 | ||
PECO Energy Co [Member] | Merger integration costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | Under-recovered revenue decoupling | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | Securitized stranded costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | Removal costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | DC PLUG charge | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
PECO Energy Co [Member] | Storm Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
PECO Energy Co [Member] | Other | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 31 | ||
Baltimore Gas and Electric Company [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 571 | ||
Current regulatory assets | 177 | 174 | |
Noncurrent regulatory assets | 398 | 397 | |
Baltimore Gas and Electric Company [Member] | Pension and Other Postretirement Plans Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Pension and Post Retirement Plan Merger Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Deferred income taxes | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Baltimore Gas and Electric Company [Member] | Advanced Metering Infrastructure Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 129 | ||
Baltimore Gas and Electric Company [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 48 | 53 | $ 56 |
Baltimore Gas and Electric Company [Member] | Advanced Metering Infrastructure Incremental Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 32 | 32 | |
Baltimore Gas and Electric Company [Member] | Electric Distribution Formula Rate Annual Reconciliations [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Electric Distribution Formula Rate One-time Events [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Energy efficiency costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Fair value of long-term debt | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Fair value of PHI's unamortized energy contracts | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Asset retirement obligations | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 14 | ||
Baltimore Gas and Electric Company [Member] | MGP remediation costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Baltimore Gas and Electric Company [Member] | Renewable Energy Program [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Baltimore Gas and Electric Company [Member] | Electric Energy and Natural Gas Costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 16 | ||
Baltimore Gas and Electric Company [Member] | Under Recovered Transmission Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 4 | 7 | |
Baltimore Gas and Electric Company [Member] | Energy efficiency and demand response programs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 285 | ||
Baltimore Gas and Electric Company [Member] | Merger integration costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 6 | ||
Baltimore Gas and Electric Company [Member] | Under-recovered revenue decoupling | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 14 | ||
Baltimore Gas and Electric Company [Member] | Securitized stranded costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | ||
Baltimore Gas and Electric Company [Member] | Removal costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | DC PLUG charge | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Storm Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Other | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 15 | ||
Pepco Holdings LLC [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 3,047 | ||
Current regulatory assets | 489 | 554 | |
Noncurrent regulatory assets | 2,312 | 2,493 | |
Pepco Holdings LLC [Member] | Pension and Other Postretirement Plans Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Pepco Holdings LLC [Member] | Pension and Post Retirement Plan Merger Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Pepco Holdings LLC [Member] | Deferred income taxes | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 10 | 9 | |
Pepco Holdings LLC [Member] | Advanced Metering Infrastructure Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 89 | 101 | |
Pepco Holdings LLC [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 120 | 134 | |
Pepco Holdings LLC [Member] | Advanced Metering Infrastructure Incremental Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Pepco Holdings LLC [Member] | Electric Distribution Formula Rate Annual Reconciliations [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Pepco Holdings LLC [Member] | Electric Distribution Formula Rate One-time Events [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Pepco Holdings LLC [Member] | Energy efficiency costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Pepco Holdings LLC [Member] | Fair value of long-term debt | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 569 | 619 | |
Pepco Holdings LLC [Member] | Fair value of PHI's unamortized energy contracts | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 561 | 750 | |
Pepco Holdings LLC [Member] | Asset retirement obligations | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 1 | 0 | |
Pepco Holdings LLC [Member] | MGP remediation costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Pepco Holdings LLC [Member] | Renewable Energy Program [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 2 | |
Pepco Holdings LLC [Member] | Electric Energy and Natural Gas Costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 93 | 30 | |
Pepco Holdings LLC [Member] | Under Recovered Transmission Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 31 | 22 | |
Pepco Holdings LLC [Member] | Energy efficiency and demand response programs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 255 | 310 | |
Pepco Holdings LLC [Member] | Merger integration costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 39 | 39 | |
Pepco Holdings LLC [Member] | Under-recovered revenue decoupling | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 57 | 41 | |
Pepco Holdings LLC [Member] | Securitized stranded costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 50 | 79 | |
Pepco Holdings LLC [Member] | Removal costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 564 | 529 | |
Pepco Holdings LLC [Member] | DC PLUG charge | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 159 | 190 | |
Pepco Holdings LLC [Member] | Storm Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 41 | 27 | |
Pepco Holdings LLC [Member] | Other | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 162 | 165 | |
Potomac Electric Power Company [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 891 | ||
Current regulatory assets | 270 | 213 | |
Noncurrent regulatory assets | 643 | 678 | |
Potomac Electric Power Company [Member] | Pension and Other Postretirement Plans Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Pension and Post Retirement Plan Merger Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Deferred income taxes | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 10 | 9 | |
Potomac Electric Power Company [Member] | Advanced Metering Infrastructure Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 50 | 58 | |
Potomac Electric Power Company [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 90 | 100 | |
Potomac Electric Power Company [Member] | Advanced Metering Infrastructure Incremental Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Electric Distribution Formula Rate Annual Reconciliations [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Electric Distribution Formula Rate One-time Events [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Energy efficiency costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Fair value of long-term debt | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Fair value of PHI's unamortized energy contracts | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Asset retirement obligations | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 1 | 0 | |
Potomac Electric Power Company [Member] | MGP remediation costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Renewable Energy Program [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Electric Energy and Natural Gas Costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 84 | 8 | |
Potomac Electric Power Company [Member] | Under Recovered Transmission Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 10 | 3 | |
Potomac Electric Power Company [Member] | Energy efficiency and demand response programs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 188 | 229 | |
Potomac Electric Power Company [Member] | Merger integration costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 18 | 20 | |
Potomac Electric Power Company [Member] | Under-recovered revenue decoupling | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 57 | 38 | |
Potomac Electric Power Company [Member] | Securitized stranded costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Potomac Electric Power Company [Member] | Removal costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 158 | 150 | |
Potomac Electric Power Company [Member] | DC PLUG charge | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 159 | 190 | |
Potomac Electric Power Company [Member] | Storm Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 9 | 7 | |
Potomac Electric Power Company [Member] | Other | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 79 | 79 | |
Delmarva Power & Light Company [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 314 | ||
Current regulatory assets | 59 | 69 | |
Noncurrent regulatory assets | 231 | 245 | |
Delmarva Power & Light Company [Member] | Pension and Other Postretirement Plans Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Pension and Post Retirement Plan Merger Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Deferred income taxes | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Advanced Metering Infrastructure Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 39 | 43 | |
Delmarva Power & Light Company [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 30 | 34 | |
Delmarva Power & Light Company [Member] | Advanced Metering Infrastructure Incremental Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Electric Distribution Formula Rate Annual Reconciliations [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Electric Distribution Formula Rate One-time Events [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Energy efficiency costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair value of long-term debt | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair value of PHI's unamortized energy contracts | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Asset retirement obligations | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | MGP remediation costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Renewable Energy Program [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 1 | |
Delmarva Power & Light Company [Member] | Electric Energy and Natural Gas Costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 7 | |
Delmarva Power & Light Company [Member] | Under Recovered Transmission Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 14 | 8 | |
Delmarva Power & Light Company [Member] | Energy efficiency and demand response programs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 67 | 81 | |
Delmarva Power & Light Company [Member] | Merger integration costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 11 | 10 | |
Delmarva Power & Light Company [Member] | Under-recovered revenue decoupling | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 3 | |
Delmarva Power & Light Company [Member] | Securitized stranded costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Removal costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 97 | 93 | |
Delmarva Power & Light Company [Member] | DC PLUG charge | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Delmarva Power & Light Company [Member] | Storm Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 4 | 5 | |
Delmarva Power & Light Company [Member] | Other | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 28 | 29 | |
Atlantic City Electric Company [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 430 | ||
Current regulatory assets | 40 | 71 | |
Noncurrent regulatory assets | 386 | 359 | |
Atlantic City Electric Company [Member] | Pension and Other Postretirement Plans Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Pension and Post Retirement Plan Merger Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Deferred income taxes | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Advanced Metering Infrastructure Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Advanced Metering Infrastructure Legacy Meter Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Advanced Metering Infrastructure Incremental Deployment Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Electric Distribution Formula Rate Annual Reconciliations [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Electric Distribution Formula Rate One-time Events [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Energy efficiency costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair value of long-term debt | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair value of PHI's unamortized energy contracts | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Asset retirement obligations | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | MGP remediation costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Renewable Energy Program [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 1 | |
Atlantic City Electric Company [Member] | Electric Energy and Natural Gas Costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 9 | 15 | |
Atlantic City Electric Company [Member] | Under Recovered Transmission Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 7 | 11 | |
Atlantic City Electric Company [Member] | Energy efficiency and demand response programs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Merger integration costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 10 | 9 | |
Atlantic City Electric Company [Member] | Under-recovered revenue decoupling | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Securitized stranded costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 50 | 79 | |
Atlantic City Electric Company [Member] | Removal costs | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 309 | 286 | |
Atlantic City Electric Company [Member] | DC PLUG charge | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 0 | 0 | |
Atlantic City Electric Company [Member] | Storm Costs [Member] | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | 28 | 15 | |
Atlantic City Electric Company [Member] | Other | |||
Regulatory Assets [Line Items] | |||
Regulatory Assets | $ 13 | $ 14 |
Regulatory Matters Regulatory_6
Regulatory Matters Regulatory Matters - Schedule of Regulatory Liabilities (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 |
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | $ 10,203 | $ 10,388 |
Regulatory Liability, Current | 644 | 523 |
Noncurrent regulatory liabilities | 9,559 | 9,865 |
Deferred income taxes | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 5,228 | 5,241 |
Nuclear decommissioning | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 2,606 | 3,064 |
Removal costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 1,547 | 1,573 |
Over Recovered Energy and Natural Gas Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 294 | 111 |
Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 528 | 399 |
Commonwealth Edison Co [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 6,343 | 6,577 |
Regulatory Liability, Current | 293 | 249 |
Noncurrent regulatory liabilities | 6,050 | 6,328 |
Commonwealth Edison Co [Member] | Deferred income taxes | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 2,394 | 2,479 |
Commonwealth Edison Co [Member] | Nuclear decommissioning | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 2,217 | 2,528 |
Commonwealth Edison Co [Member] | Removal costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 1,368 | 1,338 |
Commonwealth Edison Co [Member] | Over Recovered Energy and Natural Gas Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 137 | 47 |
Commonwealth Edison Co [Member] | Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 227 | 185 |
PECO Energy Co [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 596 | 690 |
Regulatory Liability, Current | 175 | 141 |
Noncurrent regulatory liabilities | 421 | 549 |
PECO Energy Co [Member] | Deferred income taxes | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 0 |
PECO Energy Co [Member] | Nuclear decommissioning | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 389 | 536 |
PECO Energy Co [Member] | Removal costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 0 |
PECO Energy Co [Member] | Over Recovered Energy and Natural Gas Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 132 | 60 |
PECO Energy Co [Member] | Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 75 | 94 |
Baltimore Gas and Electric Company [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 1,269 | 1,163 |
Regulatory Liability, Current | 77 | 62 |
Noncurrent regulatory liabilities | 1,192 | 1,101 |
Baltimore Gas and Electric Company [Member] | Deferred income taxes | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 1,132 | 1,032 |
Baltimore Gas and Electric Company [Member] | Nuclear decommissioning | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Removal costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 52 | 105 |
Baltimore Gas and Electric Company [Member] | Over Recovered Energy and Natural Gas Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 6 | 0 |
Baltimore Gas and Electric Company [Member] | Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 79 | 26 |
Pepco Holdings LLC [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 1,948 | 1,928 |
Regulatory Liability, Current | 84 | 56 |
Noncurrent regulatory liabilities | 1,864 | 1,872 |
Pepco Holdings LLC [Member] | Deferred income taxes | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 1,702 | 1,730 |
Pepco Holdings LLC [Member] | Nuclear decommissioning | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 0 |
Pepco Holdings LLC [Member] | Removal costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 127 | 130 |
Pepco Holdings LLC [Member] | Over Recovered Energy and Natural Gas Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 19 | 4 |
Pepco Holdings LLC [Member] | Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 100 | 64 |
Potomac Electric Power Company [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 829 | 832 |
Regulatory Liability, Current | 7 | 3 |
Noncurrent regulatory liabilities | 822 | 829 |
Potomac Electric Power Company [Member] | Deferred income taxes | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 798 | 809 |
Potomac Electric Power Company [Member] | Nuclear decommissioning | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 0 |
Potomac Electric Power Company [Member] | Removal costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 20 | 20 |
Potomac Electric Power Company [Member] | Over Recovered Energy and Natural Gas Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 0 |
Potomac Electric Power Company [Member] | Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 11 | 3 |
Delmarva Power & Light Company [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 665 | 635 |
Regulatory Liability, Current | 59 | 42 |
Noncurrent regulatory liabilities | 606 | 593 |
Delmarva Power & Light Company [Member] | Deferred income taxes | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 510 | 510 |
Delmarva Power & Light Company [Member] | Nuclear decommissioning | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 0 |
Delmarva Power & Light Company [Member] | Removal costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 107 | 110 |
Delmarva Power & Light Company [Member] | Over Recovered Energy and Natural Gas Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 18 | 1 |
Delmarva Power & Light Company [Member] | Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 30 | 14 |
Atlantic City Electric Company [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 420 | 422 |
Regulatory Liability, Current | 18 | 11 |
Noncurrent regulatory liabilities | 402 | 411 |
Atlantic City Electric Company [Member] | Deferred income taxes | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 394 | 411 |
Atlantic City Electric Company [Member] | Nuclear decommissioning | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 0 |
Atlantic City Electric Company [Member] | Removal costs | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 0 | 0 |
Atlantic City Electric Company [Member] | Over Recovered Energy and Natural Gas Costs [Member] | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | 1 | 3 |
Atlantic City Electric Company [Member] | Other | ||
Regulatory Liabilities [Line Items] | ||
Regulatory Liabilities | $ 25 | $ 8 |
Regulatory Matters Regulatory_7
Regulatory Matters Regulatory Matters - Capitalized Ratemaking Amounts Not Recognized (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes | $ 65 | $ 69 | |
Commonwealth Edison Co [Member] | |||
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes | [1] | 8 | 6 |
PECO Energy Co [Member] | |||
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | |||
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes | [2] | 49 | 53 |
Pepco Holdings LLC [Member] | |||
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes | 8 | 10 | |
Potomac Electric Power Company [Member] | |||
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes | [3] | 5 | 6 |
Delmarva Power & Light Company [Member] | |||
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes | [3] | 3 | 4 |
Atlantic City Electric Company [Member] | |||
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes | $ 0 | $ 0 | |
[1] | Reflects ComEd's unrecognized equity returns earned for ratemaking purposes on its electric distribution formula rate regulatory assets. | ||
[2] | BGE's authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholders' investment on its AMI programs | ||
[3] | Pepco's and DPL's authorized amounts capitalized for ratemaking purposes relate to earnings on shareholders' investment on their respective AMI Programs and Energy Efficiency and Demand Response Programs. The earnings on energy efficiency are on Pepco DC and DPL DE programs only. |
Regulatory Matters Regulatory_8
Regulatory Matters Regulatory Matters - Schedule of Completed Rate Cases (Details) - USD ($) $ in Millions | Jan. 15, 2019 | Jan. 04, 2019 | Dec. 20, 2018 | Dec. 04, 2018 | Sep. 07, 2018 | Jun. 27, 2018 | Jun. 08, 2018 | May 31, 2018 | Apr. 20, 2018 | [4] | Apr. 17, 2018 | Apr. 16, 2018 | Mar. 29, 2018 | Mar. 08, 2018 | [4] | Feb. 09, 2018 | Dec. 19, 2017 | Dec. 18, 2017 | Nov. 16, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2023 | |||
Commonwealth Edison Co [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [1],[2] | $ (26) | |||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | [1] | 8.32% | |||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [1] | $ (44) | |||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [1],[3] | 11.50% | |||||||||||||||||||||||
Commonwealth Edison Co [Member] | Electric Distribution [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [4] | $ (24) | $ (23) | ||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 34 | ||||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 6.52% | ||||||||||||||||||||||||
Public Utilities, Requested Equity Capital Structure, Percentage | 8.69% | ||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ (58) | ||||||||||||||||||||||||
PECO Energy Co [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 22 | ||||||||||||||||||||||||
Public Utilities, Requested Equity Capital Structure, Percentage | 11.00% | ||||||||||||||||||||||||
PECO Energy Co [Member] | Electric Distribution [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [4] | $ 25 | |||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [4] | $ 82 | |||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [1],[2],[5] | $ 26 | |||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | [1] | 7.61% | |||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [1] | $ 10 | |||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 10.50% | ||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | Gas Distribution [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 43 | ||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 61 | ||||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 9.80% | ||||||||||||||||||||||||
Potomac Electric Power Company [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [2] | $ 8 | |||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 7.82% | ||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 6 | ||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [3] | 10.50% | |||||||||||||||||||||||
Potomac Electric Power Company [Member] | Electric Distribution [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 4 | $ (15) | $ (24) | [4] | $ 3 | ||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 30 | $ 66 | |||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 10.30% | 9.50% | 9.525% | ||||||||||||||||||||||
Delmarva Power & Light Company [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [2] | $ 27 | |||||||||||||||||||||||
Public Utilities, Approved Equity Capital Structure, Percentage | 7.29% | ||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 14 | ||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | [3] | 10.50% | |||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Electric Distribution [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | $ 12 | [4] | $ 19 | ||||||||||||||||||||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 13 | ||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [4] | $ (7) | |||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 9.70% | ||||||||||||||||||||||||
Public Utilities, Approved Return on Equity, Percentage | 9.50% | ||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Gas Distribution [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [4] | $ 4 | |||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [4] | $ (4) | |||||||||||||||||||||||
Public Utilities, Requested Return on Equity, Percentage | 9.70% | ||||||||||||||||||||||||
Subsequent Event [Member] | Baltimore Gas and Electric Company [Member] | |||||||||||||||||||||||||
Regulatory Matters Completed Rate Cases [Line Items] | |||||||||||||||||||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 200 | ||||||||||||||||||||||||
[1] | The time period for any formal challenges to the annual transmission formula rate update filings expired with no formal challenges submitted. | ||||||||||||||||||||||||
[2] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246MzY0MUFFQzNGNTE3Mzk3OTI2RjIxNTRFRUQyNkYyMzMM} | ||||||||||||||||||||||||
[3] | As part of the FERC-approved settlement of ComEd’s 2007 transmission rate case, the rate of return on common equity is 11.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO, and the common equity component of the ratio used to calculate the weighted average debt and equity return for the transmission formula rate is currently capped at 55%. As part of the FERC-approved settlement of the ROE complaint against BGE, Pepco, DPL and ACE, the rate of return on common equity is 10.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO. | ||||||||||||||||||||||||
[4] | Includes the annual ongoing TCJA tax savings further discussed below. | ||||||||||||||||||||||||
[5] | BGE's transmission revenue requirement includes a FERC approved dedicated facilities charge of $12 million to recover the costs of providing transmission service to specifically designated load by BGE. |
Regulatory Matters Regulatory_9
Regulatory Matters Regulatory Matters - Schedule of Pending Rate Cases (Details) - USD ($) $ in Millions | Jan. 15, 2019 | Nov. 19, 2018 | Aug. 21, 2018 | May 31, 2018 | Apr. 17, 2018 | Dec. 19, 2017 | Dec. 31, 2018 | |
Atlantic City Electric Company [Member] | ||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 40 | $ 4 | ||||||
Atlantic City Electric Company [Member] | Electric Distribution [Member] | ||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [1] | $ 122 | ||||||
Public Utilities, Requested Return on Equity, Percentage | 10.10% | |||||||
Potomac Electric Power Company [Member] | ||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 6 | |||||||
Potomac Electric Power Company [Member] | Electric Distribution [Member] | ||||||||
Regulatory Matters Pending Rate Cases [Line Items] | ||||||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ 30 | $ 66 | ||||||
Public Utilities, Requested Return on Equity, Percentage | 10.30% | 9.50% | 9.525% | |||||
[1] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246NUYyM0EwMDI1MDhGQUUyMUZEMzExNTNGOUY0NjExNDUM} |
Regulatory Matters Regulator_10
Regulatory Matters Regulatory Matters - Schedule of TCJA Savings (Details) - USD ($) $ in Millions | Sep. 07, 2018 | Aug. 29, 2018 | Jul. 01, 2018 | Jun. 27, 2018 | Apr. 20, 2018 | Mar. 29, 2018 | Mar. 02, 2018 | Feb. 09, 2018 | Feb. 06, 2018 | Feb. 05, 2018 | Jan. 31, 2018 | Jan. 18, 2018 | Sep. 30, 2018 |
Commonwealth Edison Co [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 201 | ||||||||||||
PECO Energy Co [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 71 | ||||||||||||
Atlantic City Electric Company [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 23 | ||||||||||||
Gas Distribution [Member] | PECO Energy Co [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 4 | ||||||||||||
Gas Distribution [Member] | Baltimore Gas and Electric Company [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 31 | ||||||||||||
Public Utilities, Rate Credit | 2 | ||||||||||||
Gas Distribution [Member] | Delmarva Power & Light Company [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 7 | ||||||||||||
Public Utilities, Rate Credit | $ 1 | ||||||||||||
Electric Distribution [Member] | PECO Energy Co [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Public Utilities, Rate Credit | 67 | ||||||||||||
Electric Distribution [Member] | Baltimore Gas and Electric Company [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 72 | ||||||||||||
Electric Distribution [Member] | Delmarva Power & Light Company [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 19 | ||||||||||||
Public Utilities, Rate Credit | $ 3 | ||||||||||||
Electric Distribution [Member] | Potomac Electric Power Company [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 39 | ||||||||||||
Public Utilities, Rate Credit | $ 20 | $ 10 | |||||||||||
Electric Distribution [Member] | Atlantic City Electric Company [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Public Utilities, Rate Credit | $ 6 | ||||||||||||
Maryland Service Territory [Member] | Electric Distribution [Member] | Delmarva Power & Light Company [Member] | |||||||||||||
Regulatory Matters Schedule of TCJA Savings [Line Items] | |||||||||||||
Tax Savings From Tax Cuts and Jobs Act | $ 31 | $ 14 | |||||||||||
Public Utilities, Rate Credit | $ 2 |
Regulatory Matters Regulator_11
Regulatory Matters Regulatory Matters - Schedule of Revenue Increases (Decreases) (Details) - Commonwealth Edison Co [Member] - USD ($) $ in Millions | Dec. 04, 2018 | Apr. 16, 2018 | Dec. 31, 2018 | Dec. 31, 2017 | |
Public Utilities, General Disclosures [Line Items] | |||||
Public Utilities, Requested Rate Increase (Decrease), Amount | [1] | $ (44) | |||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [1],[2] | (26) | |||
Electric Distribution [Member] | |||||
Public Utilities, General Disclosures [Line Items] | |||||
Public Utilities, Requested Rate Increase (Decrease), Amount | $ (58) | ||||
Public Utilities, Approved Rate Increase (Decrease), Amount | $ 34 | ||||
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount | [3] | $ (24) | $ (23) | ||
Public Utilities, Requested Equity Capital Structure, Percentage | 8.69% | ||||
[1] | The time period for any formal challenges to the annual transmission formula rate update filings expired with no formal challenges submitted. | ||||
[2] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246MzY0MUFFQzNGNTE3Mzk3OTI2RjIxNTRFRUQyNkYyMzMM} | ||||
[3] | Includes the annual ongoing TCJA tax savings further discussed below. |
Mergers, Acquisitions and Dis_3
Mergers, Acquisitions and Dispositions Mergers, Acquisitions and Dispositions - Narrative (Details) $ in Millions | Jul. 09, 2018USD ($) | Apr. 04, 2018USD ($) | Feb. 28, 2018USD ($) | Nov. 07, 2017USD ($) | Mar. 31, 2017USD ($) | Sep. 01, 2016USD ($) | Jun. 16, 2016USD ($) | Mar. 23, 2016USD ($) | Dec. 31, 2018USD ($)MW | Sep. 30, 2018USD ($) | Jun. 30, 2018USD ($) | Mar. 31, 2018USD ($) | Dec. 31, 2017USD ($) | Sep. 30, 2017USD ($) | Jun. 30, 2017USD ($) | Mar. 31, 2017USD ($) | Dec. 31, 2016USD ($) | Mar. 23, 2016USD ($) | Sep. 30, 2017USD ($) | Dec. 31, 2016USD ($) | Dec. 31, 2016USD ($) | Dec. 31, 2018USD ($)MW | Dec. 31, 2017USD ($)MW | Dec. 31, 2016USD ($) | Jun. 30, 2016USD ($) | Mar. 24, 2016USD ($) | ||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Assets held for sale | $ 904 | $ 0 | $ 904 | $ 0 | ||||||||||||||||||||||||||
Liabilities held for sale | 777 | 0 | 777 | 0 | ||||||||||||||||||||||||||
Asset Retirement Obligation, Revision of Estimate | 20 | $ 2 | ||||||||||||||||||||||||||||
Deconsolidation, Gain (Loss), Amount | $ 213 | 0 | 213 | 0 | ||||||||||||||||||||||||||
Business Combination, Contingent Consideration, Asset | $ 235 | |||||||||||||||||||||||||||||
Payments to Acquire Businesses, Gross | 154 | 208 | 6,923 | |||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 7 | [1] | 16 | [1] | 143 | |||||||||||||||||||||||||
Line of credit facility, maximum borrowing capacity | [2] | 9,704 | 9,704 | |||||||||||||||||||||||||||
Other Commitment | 127 | 127 | ||||||||||||||||||||||||||||
Revenues | 8,814 | $ 9,403 | $ 8,076 | $ 9,693 | 8,384 | $ 8,768 | $ 7,665 | $ 8,747 | 35,985 | 33,565 | 31,366 | |||||||||||||||||||
Business Combination, Bargain Purchase, Gain Recognized, Amount | 0 | 233 | 0 | |||||||||||||||||||||||||||
Net income (Loss) | 2,084 | 3,876 | 1,196 | |||||||||||||||||||||||||||
Noncash Merger Related Costs | $ 0 | [3] | $ 0 | [4] | 558 | [5],[6] | ||||||||||||||||||||||||
Wind Assets [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Non-Financial Commitment1 | MW | 40 | |||||||||||||||||||||||||||||
Exelon Corporation Affiliate [Member] | Commitment Adjustment [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | $ 5 | $ 5 | ||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Wind Assets [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Non-Financial Commitment1 | MW | 40 | 120 | 40 | |||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Remaining Commitment [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | $ 12 | $ 12 | ||||||||||||||||||||||||||||
Exelon Consolidations [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 508 | 508 | ||||||||||||||||||||||||||||
Exelon Consolidations [Member] | Rate Bill Credits [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 259 | 259 | ||||||||||||||||||||||||||||
Exelon Consolidations [Member] | Other1 [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 29 | 29 | ||||||||||||||||||||||||||||
Exelon Consolidations [Member] | Energy Efficiency Program [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 117 | 117 | ||||||||||||||||||||||||||||
Exelon Consolidations [Member] | Charitable Contributions [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 50 | 50 | ||||||||||||||||||||||||||||
Exelon Consolidations [Member] | Delivery System Modernization [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 22 | 22 | ||||||||||||||||||||||||||||
Exelon Consolidations [Member] | Green Sustainability Fund [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 14 | 14 | ||||||||||||||||||||||||||||
Exelon Consolidations [Member] | Workforce Development [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 17 | 17 | ||||||||||||||||||||||||||||
Exelon Consolidations [Member] | Remaining Commitment [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 128 | 128 | ||||||||||||||||||||||||||||
Pepco Holdings [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Payments to Acquire Businesses, Gross | $ 7,142 | |||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Revenues | 4,670 | $ 4,829 | 3,785 | |||||||||||||||||||||||||||
Net income (Loss) | $ 453 | $ 364 | (66) | |||||||||||||||||||||||||||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets | $ 4,005 | $ 4,005 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Other Solar Projects [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Non-Financial Commitment1 | MW | 27 | 37 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Wind Assets [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Non-Financial Commitment1 | MW | 100 | |||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Commitments [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | $ 513 | $ 513 | $ 513 | 513 | ||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Remaining Commitment [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 92 | $ 92 | ||||||||||||||||||||||||||||
ConEdison Solutions [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Payments to Acquire Businesses, Gross | $ 257 | |||||||||||||||||||||||||||||
Net Working Capital | $ 204 | |||||||||||||||||||||||||||||
Oyster Creek [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Assets held for sale | 897 | 897 | ||||||||||||||||||||||||||||
Baltimore Gas and Electric Company [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | ||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 1 | [1],[7] | $ 4 | [1],[7] | (1) | |||||||||||||||||||||||||
Revenues | 799 | 731 | 662 | 977 | 813 | 738 | 674 | 951 | 3,169 | 3,176 | 3,233 | |||||||||||||||||||
Net income (Loss) | 71 | 63 | 51 | 128 | 76 | 62 | 45 | 125 | 313 | 307 | 294 | |||||||||||||||||||
Noncash Merger Related Costs | 0 | [3] | 0 | [4] | 0 | [5],[6] | ||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Assets held for sale | 904 | 0 | 904 | 0 | ||||||||||||||||||||||||||
Liabilities held for sale | 777 | 0 | 777 | 0 | ||||||||||||||||||||||||||
Asset Retirement Obligation, Revision of Estimate | 203 | 84 | $ 138 | 0 | 0 | |||||||||||||||||||||||||
Deconsolidation, Gain (Loss), Amount | 0 | 213 | 0 | |||||||||||||||||||||||||||
Proceeds from Divestiture of Businesses | $ 87 | |||||||||||||||||||||||||||||
Membership interest | 9,518 | 9,357 | 9,518 | 9,357 | ||||||||||||||||||||||||||
Business Combination, Contingent Consideration, Asset | 163 | |||||||||||||||||||||||||||||
Payments to Acquire Businesses, Gross | 154 | 208 | 293 | |||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 5 | [1] | 22 | [1] | 37 | |||||||||||||||||||||||||
Line of credit facility, maximum borrowing capacity | 200 | 45 | 200 | |||||||||||||||||||||||||||
Gain (Loss) on Disposition of Property Plant Equipment | 10 | 69 | ||||||||||||||||||||||||||||
Proceeds from Sale of Productive Assets | $ 37 | |||||||||||||||||||||||||||||
Revenues | 5,069 | 5,278 | 4,579 | 5,512 | 4,657 | 4,750 | 4,216 | 4,878 | 20,437 | 18,500 | 17,757 | |||||||||||||||||||
Business Combination, Bargain Purchase, Gain Recognized, Amount | 0 | 233 | 0 | |||||||||||||||||||||||||||
Net income (Loss) | 443 | 2,798 | 550 | |||||||||||||||||||||||||||
Noncash Merger Related Costs | 0 | [3] | 0 | [4] | 53 | [5],[6] | ||||||||||||||||||||||||
Asset Impairment Charges | $ 23 | |||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | FirstEnergy [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Payments to Acquire Businesses, Gross | $ 140 | |||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | Handley [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Payments to Acquire Businesses, Gross | $ 62 | |||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | Fitzpatrick [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Business Combination, Consideration Transferred | $ 289 | 289 | ||||||||||||||||||||||||||||
Payments to Acquire Businesses, Gross | 110 | |||||||||||||||||||||||||||||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets | 60 | 60 | ||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 57 | |||||||||||||||||||||||||||||
Business Combination, Consideration Transferred, Other | 179 | 54 | ||||||||||||||||||||||||||||
Business Combination, Bargain Purchase, Gain Recognized, Amount | 233 | |||||||||||||||||||||||||||||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Deferred Tax Liabilities Noncurrent | 149 | 149 | ||||||||||||||||||||||||||||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Assets | 114 | 114 | ||||||||||||||||||||||||||||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Financial Liabilities | 444 | 444 | ||||||||||||||||||||||||||||
Total net assets | 522 | 522 | ||||||||||||||||||||||||||||
Exelon Generation Co L L C [Member] | Fitzpatrick [Member] | Cash and Cash Equivalents [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Business Combination, Consideration Transferred | 110 | |||||||||||||||||||||||||||||
Payments to Acquire Businesses, Gross | 125 | |||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Membership interest | 9,220 | 8,835 | 9,220 | 8,835 | ||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 0 | [1],[7] | (6) | [1],[7] | 28 | |||||||||||||||||||||||||
Other Commitment | $ 444 | 444 | ||||||||||||||||||||||||||||
Revenues | 1,117 | 1,361 | 1,076 | 1,251 | 1,121 | 1,310 | 1,074 | 1,175 | 4,805 | 4,679 | ||||||||||||||||||||
Net income (Loss) | 398 | 362 | ||||||||||||||||||||||||||||
Noncash Merger Related Costs | 5 | [3] | (8) | [4] | ||||||||||||||||||||||||||
Impairment of Long-Lived Assets to be Disposed of | 25 | |||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | |||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | [7] | 29 | ||||||||||||||||||||||||||||
Revenues | 1,153 | |||||||||||||||||||||||||||||
Net income (Loss) | 19 | |||||||||||||||||||||||||||||
Noncash Merger Related Costs | [5],[6] | $ 0 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Successor [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Asset Retirement Obligation, Revision of Estimate | 2 | 20 | ||||||||||||||||||||||||||||
Business Combination, Contingent Consideration, Asset | 235 | |||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | [7] | 69 | 0 | (18) | [1] | |||||||||||||||||||||||||
Business Combination, Consideration Transferred, Other | 59 | |||||||||||||||||||||||||||||
Revenues | 3,643 | 4,679 | ||||||||||||||||||||||||||||
Net income (Loss) | $ (61) | (61) | ||||||||||||||||||||||||||||
Noncash Merger Related Costs | [5],[6] | $ 317 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 320 | 320 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | Rate Bill Credits [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 264 | 264 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | Other1 [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 6 | 6 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | Energy Efficiency Program [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | Charitable Contributions [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 50 | 50 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | Delivery System Modernization [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | Green Sustainability Fund [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | Workforce Development [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Asset Retirement Obligation, Revision of Estimate | 22 | 0 | ||||||||||||||||||||||||||||
Revenues | 531 | 628 | 523 | 557 | 510 | 604 | 514 | 530 | 2,239 | 2,158 | 2,186 | |||||||||||||||||||
Net income (Loss) | 36 | 89 | 54 | 31 | 17 | 87 | 43 | 58 | 210 | 205 | 42 | |||||||||||||||||||
Noncash Merger Related Costs | 0 | [3] | (6) | [4] | 125 | [5],[6] | ||||||||||||||||||||||||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets | 2,100 | |||||||||||||||||||||||||||||
Fresh-Start Adjustment, Increase (Decrease), Goodwill | 400 | |||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Commitments [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Additional Capital | $ 73 | |||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 120 | 120 | ||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Pepco Holdings LLC [Member] | Rate Bill Credits [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 91 | 91 | ||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Pepco Holdings LLC [Member] | Other1 [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 1 | 1 | ||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Pepco Holdings LLC [Member] | Energy Efficiency Program [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Pepco Holdings LLC [Member] | Charitable Contributions [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 28 | 28 | ||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Pepco Holdings LLC [Member] | Delivery System Modernization [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Pepco Holdings LLC [Member] | Green Sustainability Fund [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Potomac Electric Power Company [Member] | Pepco Holdings LLC [Member] | Workforce Development [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Asset Retirement Obligation, Revision of Estimate | (1) | 1 | ||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 0 | [1],[7] | (7) | [1],[7] | 20 | |||||||||||||||||||||||||
Revenues | 331 | 328 | 289 | 384 | 330 | 327 | 282 | 362 | 1,332 | 1,300 | 1,277 | |||||||||||||||||||
Net income (Loss) | 30 | 33 | 26 | 31 | 14 | 31 | 19 | 57 | 120 | 121 | (9) | |||||||||||||||||||
Noncash Merger Related Costs | 5 | [3] | (2) | [4] | 82 | [5],[6] | ||||||||||||||||||||||||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets | 1,400 | |||||||||||||||||||||||||||||
Fresh-Start Adjustment, Increase (Decrease), Goodwill | 300 | |||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Commitments [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Additional Capital | 46 | |||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 89 | 89 | ||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Pepco Holdings LLC [Member] | Rate Bill Credits [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 72 | 72 | ||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Pepco Holdings LLC [Member] | Commitment Adjustment [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 5 | 5 | ||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Pepco Holdings LLC [Member] | Other1 [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 5 | 5 | ||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Pepco Holdings LLC [Member] | Energy Efficiency Program [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Pepco Holdings LLC [Member] | Charitable Contributions [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 12 | 12 | ||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Pepco Holdings LLC [Member] | Delivery System Modernization [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Pepco Holdings LLC [Member] | Green Sustainability Fund [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Delmarva Power & Light Company [Member] | Pepco Holdings LLC [Member] | Workforce Development [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Asset Retirement Obligation, Revision of Estimate | (1) | 2 | ||||||||||||||||||||||||||||
Business Combination, Integration Related Costs | 0 | [1],[7] | (6) | [1],[7] | 19 | |||||||||||||||||||||||||
Revenues | 254 | 406 | 265 | 310 | 271 | 370 | 270 | 275 | 1,236 | 1,186 | 1,257 | |||||||||||||||||||
Net income (Loss) | (1) | $ 61 | 8 | $ 7 | $ 0 | $ 41 | 8 | $ 28 | 75 | 77 | (42) | |||||||||||||||||||
Noncash Merger Related Costs | 0 | [3] | $ 0 | [4] | $ 110 | [5],[6] | ||||||||||||||||||||||||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets | 500 | |||||||||||||||||||||||||||||
Fresh-Start Adjustment, Increase (Decrease), Goodwill | $ (700) | |||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Commitments [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Additional Capital | $ 49 | |||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Pepco Holdings LLC [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 111 | 111 | ||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Pepco Holdings LLC [Member] | Rate Bill Credits [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 101 | 101 | ||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Pepco Holdings LLC [Member] | Other1 [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Pepco Holdings LLC [Member] | Energy Efficiency Program [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Pepco Holdings LLC [Member] | Charitable Contributions [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 10 | 10 | ||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Pepco Holdings LLC [Member] | Delivery System Modernization [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Pepco Holdings LLC [Member] | Green Sustainability Fund [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Atlantic City Electric Company [Member] | Pepco Holdings LLC [Member] | Workforce Development [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | 0 | 0 | ||||||||||||||||||||||||||||
Exelon Corporation Affiliate [Member] | Other commitments [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Other Commitment | $ 83 | $ 83 | ||||||||||||||||||||||||||||
Electricity Generation Plant, Non-Nuclear [Member] | ||||||||||||||||||||||||||||||
Business Acquisition [Line Items] | ||||||||||||||||||||||||||||||
Impairment of Long-Lived Assets to be Disposed of | $ 41 | $ 460 | $ 460 | |||||||||||||||||||||||||||
[1] | The costs incurred are classified primarily within Operating and maintenance expense in the Registrants’ respective Consolidated Statements of Operations and Comprehensive Income, with the exception of the financing costs, which are included within Interest expense. Costs do not include merger commitments discussed above. | |||||||||||||||||||||||||||||
[2] | Excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million, $33 million, $34 million, $5 million, $5 million, $5 million and $5 million, respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. As of December 31, 2018, letters of credit issued under these facilities totaled $5 million and $2 million for Generation and BGE, respectively. | |||||||||||||||||||||||||||||
[3] | See Note 5 - Mergers, Acquisitions and Dispositions for additional information. | |||||||||||||||||||||||||||||
[4] | See Note 5 - Mergers, Acquisitions and Dispositions for additional information. | |||||||||||||||||||||||||||||
[5] | Excludes $5 million of forgiveness of Accounts receivable related to merger commitments recorded in connection with the PHI Merger, the balance is included within Provision for uncollectible accounts. | |||||||||||||||||||||||||||||
[6] | See Note 5 - Mergers, Acquisitions and Dispositions for additional information. | |||||||||||||||||||||||||||||
[7] | (b)For the year ended December 31, 2017, includes deferrals of previously incurred integration costs as regulatory assets of $24 million, $8 million, $8 million, and $8 million at PHI, Pepco, DPL and ACE, respectively. For the year ended December 31, 2016, includes deferrals of previously incurred integration costs as regulatory assets of $8 million, $6 million, $11 million and $4 million at ComEd, BGE, Pepco and DPL, respectively. For the Successor period March 24, 2016 to December 31, 2016, includes deferrals of previously incurred integration costs as regulatory assets of $16 million at PHI. See Note 4 - Regulatory Matters for additional information. |
Mergers, Acquisitions and Dis_4
Mergers, Acquisitions and Dispositions Purchase Price Allocation Table - FitzPatrick (Details) - USD ($) $ in Millions | Mar. 31, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 |
Business Acquisition [Line Items] | ||||
Payments to Acquire Businesses, Gross | $ 154 | $ 208 | $ 6,923 | |
Business Combination, Bargain Purchase, Gain Recognized, Amount | 0 | 233 | 0 | |
Exelon Generation Co L L C [Member] | ||||
Business Acquisition [Line Items] | ||||
Payments to Acquire Businesses, Gross | 154 | 208 | 293 | |
Business Combination, Bargain Purchase, Gain Recognized, Amount | $ 0 | 233 | $ 0 | |
Exelon Generation Co L L C [Member] | Fitzpatrick [Member] | ||||
Business Acquisition [Line Items] | ||||
Payments to Acquire Businesses, Gross | 110 | |||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets | 110 | |||
Business Combination, Consideration Transferred, Other | $ 179 | 54 | ||
Business Combination, Consideration Transferred | 289 | 289 | ||
Current assets | 60 | |||
Property, plant and equipment | 298 | |||
Unamortized energy contracts | 807 | |||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Assets | 114 | |||
Total assets | 1,279 | |||
Current liabilities | 6 | |||
Unamortized energy contract liabilities | (444) | |||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Deferred Tax Liabilities Noncurrent | 149 | |||
BusinessCombinationRecognizedIdentifiableAssetsAcquiredAndLiabilitiesAssumedRegulatedLiabilities | 110 | |||
Other liabilities | (15) | |||
Total liabilities | 757 | |||
Total net assets | 522 | |||
_BusinessCombinationRecognizedIdentifiableAssetsAcquiredAndLiabilitiesAssumedRetirmentObligations | 33 | |||
Business Combination, Bargain Purchase, Gain Recognized, Amount | 233 | |||
Exelon Generation Co L L C [Member] | Fitzpatrick [Member] | Cash and Cash Equivalents [Member] | ||||
Business Acquisition [Line Items] | ||||
Payments to Acquire Businesses, Gross | $ 125 | |||
Business Combination, Consideration Transferred | $ 110 |
Mergers, Acquisitions and Dis_5
Mergers, Acquisitions and Dispositions Purchase Price allocation Table - Con Edison (Details) - USD ($) $ in Millions | Sep. 01, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 |
Business Combination Segment Allocation [Line Items] | ||||
Payments to Acquire Businesses, Gross | $ 154 | $ 208 | $ 6,923 | |
Energy Marketing Contracts Assets, Noncurrent | $ 372 | $ 395 | ||
ConEdison Solutions [Member] | ||||
Business Combination Segment Allocation [Line Items] | ||||
Payments to Acquire Businesses, Gross | $ 257 |
Mergers, Acquisitions and Dis_6
Mergers, Acquisitions and Dispositions Merger Commitments Table (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Mar. 31, 2017 |
Other Commitments [Line Items] | ||
Other Commitment | $ 127 | |
Pepco Holdings LLC [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | $ 444 | |
Exelon Consolidations [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 508 | |
Exelon Consolidations [Member] | Rate Bill Credits [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 259 | |
Exelon Consolidations [Member] | Energy Efficiency Program [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 117 | |
Exelon Consolidations [Member] | Charitable Contributions [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 50 | |
Exelon Consolidations [Member] | Delivery System Modernization [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 22 | |
Exelon Consolidations [Member] | Green Sustainability Fund [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 14 | |
Exelon Consolidations [Member] | Workforce Development [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 17 | |
Exelon Consolidations [Member] | Other1 [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 29 | |
Exelon Consolidations [Member] | Remaining Commitment [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 128 | |
Atlantic City Electric Company [Member] | Remaining Commitment [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 7 | |
Delmarva Power & Light Company [Member] | Remaining Commitment [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 12 | |
Potomac Electric Power Company [Member] | Remaining Commitment [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 73 | |
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 320 | |
Pepco Holdings LLC [Member] | Potomac Electric Power Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 120 | |
Pepco Holdings LLC [Member] | Delmarva Power & Light Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 89 | |
Pepco Holdings LLC [Member] | Atlantic City Electric Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 111 | |
Pepco Holdings LLC [Member] | Rate Bill Credits [Member] | Pepco Holdings LLC [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 264 | |
Pepco Holdings LLC [Member] | Rate Bill Credits [Member] | Potomac Electric Power Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 91 | |
Pepco Holdings LLC [Member] | Rate Bill Credits [Member] | Delmarva Power & Light Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 72 | |
Pepco Holdings LLC [Member] | Rate Bill Credits [Member] | Atlantic City Electric Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 101 | |
Pepco Holdings LLC [Member] | Energy Efficiency Program [Member] | Pepco Holdings LLC [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Energy Efficiency Program [Member] | Potomac Electric Power Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Energy Efficiency Program [Member] | Delmarva Power & Light Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Energy Efficiency Program [Member] | Atlantic City Electric Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Charitable Contributions [Member] | Pepco Holdings LLC [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 50 | |
Pepco Holdings LLC [Member] | Charitable Contributions [Member] | Potomac Electric Power Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 28 | |
Pepco Holdings LLC [Member] | Charitable Contributions [Member] | Delmarva Power & Light Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 12 | |
Pepco Holdings LLC [Member] | Charitable Contributions [Member] | Atlantic City Electric Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 10 | |
Pepco Holdings LLC [Member] | Delivery System Modernization [Member] | Pepco Holdings LLC [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Delivery System Modernization [Member] | Potomac Electric Power Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Delivery System Modernization [Member] | Delmarva Power & Light Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Delivery System Modernization [Member] | Atlantic City Electric Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Green Sustainability Fund [Member] | Pepco Holdings LLC [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Green Sustainability Fund [Member] | Potomac Electric Power Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Green Sustainability Fund [Member] | Delmarva Power & Light Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Green Sustainability Fund [Member] | Atlantic City Electric Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Workforce Development [Member] | Pepco Holdings LLC [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Workforce Development [Member] | Potomac Electric Power Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Workforce Development [Member] | Delmarva Power & Light Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Workforce Development [Member] | Atlantic City Electric Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Other1 [Member] | Pepco Holdings LLC [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 6 | |
Pepco Holdings LLC [Member] | Other1 [Member] | Potomac Electric Power Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 1 | |
Pepco Holdings LLC [Member] | Other1 [Member] | Delmarva Power & Light Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 5 | |
Pepco Holdings LLC [Member] | Other1 [Member] | Atlantic City Electric Company [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | 0 | |
Pepco Holdings LLC [Member] | Remaining Commitment [Member] | ||
Other Commitments [Line Items] | ||
Other Commitment | $ 92 |
Mergers, Acquisitions and Dis_7
Mergers, Acquisitions and Dispositions Merger Transaction Table (Details) - USD ($) $ in Millions | Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 |
Payments to Acquire Businesses, Gross | $ 154 | $ 208 | $ 6,923 | ||
Pepco Holdings [Member] | |||||
Payments to Acquire Businesses, Gross | $ 7,142 | ||||
Pepco Holdings LLC [Member] | Pepco Holdings LLC [Member] | Deferred Compensation, Share-based Payments [Member] | |||||
Stockholders' Equity, Other | $ 29 |
Mergers, Acquisitions and Dis_8
Mergers, Acquisitions and Dispositions Purchase Price Allocation Table - (PHI) (Details) $ in Millions | Mar. 23, 2016USD ($) |
Pepco Holdings LLC [Member] | |
Business Acquisition [Line Items] | |
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets | $ 4,005 |
Mergers, Acquisitions and Dis_9
Mergers, Acquisitions and Dispositions Merger Integration Related Costs Table (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||||||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Mar. 31, 2017 | ||||
Other Commitment | $ 127 | ||||||||
Business Combination, Integration Related Costs | 7 | [1] | $ 16 | [1] | $ 143 | ||||
Exelon Generation Co L L C [Member] | |||||||||
Business Combination, Integration Related Costs | 5 | [1] | 22 | [1] | 37 | ||||
PECO Energy Co [Member] | |||||||||
Business Combination, Integration Related Costs | 1 | [1] | 4 | [1] | 5 | ||||
Baltimore Gas and Electric Company [Member] | |||||||||
Business Combination, Integration Related Costs | 1 | [1],[2] | 4 | [1],[2] | (1) | ||||
Pepco Holdings LLC [Member] | |||||||||
Other Commitment | $ 444 | ||||||||
Business Combination, Integration Related Costs | 0 | [1],[2] | (6) | [1],[2] | 28 | ||||
Delmarva Power & Light Company [Member] | |||||||||
Business Combination, Integration Related Costs | 0 | [1],[2] | (7) | [1],[2] | 20 | ||||
Atlantic City Electric Company [Member] | |||||||||
Business Combination, Integration Related Costs | 0 | [1],[2] | (6) | [1],[2] | 19 | ||||
Commonwealth Edison Co [Member] | |||||||||
Business Combination, Integration Related Costs | 0 | [1],[2] | 1 | [1],[2] | $ (6) | ||||
Predecessor [Member] | Pepco Holdings LLC [Member] | |||||||||
Business Combination, Integration Related Costs | [2] | $ 29 | |||||||
Successor [Member] | Pepco Holdings LLC [Member] | |||||||||
Business Combination, Integration Related Costs | [2] | $ 69 | 0 | (18) | [1] | ||||
Regulatory Assets [Member] | Baltimore Gas and Electric Company [Member] | |||||||||
Business Combination, Integration Related Costs | 6 | ||||||||
Regulatory Assets [Member] | Pepco Holdings LLC [Member] | |||||||||
Business Combination, Integration Related Costs | 16 | 24 | |||||||
Regulatory Assets [Member] | Potomac Electric Power Company [Member] | |||||||||
Business Combination, Integration Related Costs | 11 | 8 | |||||||
Regulatory Assets [Member] | Delmarva Power & Light Company [Member] | |||||||||
Business Combination, Integration Related Costs | 4 | 8 | |||||||
Regulatory Assets [Member] | Atlantic City Electric Company [Member] | |||||||||
Business Combination, Integration Related Costs | $ 8 | ||||||||
Regulatory Assets [Member] | Commonwealth Edison Co [Member] | |||||||||
Business Combination, Integration Related Costs | $ 8 | ||||||||
Potomac Electric Power Company [Member] | Remaining Commitment [Member] | |||||||||
Other Commitment | $ 73 | ||||||||
[1] | The costs incurred are classified primarily within Operating and maintenance expense in the Registrants’ respective Consolidated Statements of Operations and Comprehensive Income, with the exception of the financing costs, which are included within Interest expense. Costs do not include merger commitments discussed above. | ||||||||
[2] | (b)For the year ended December 31, 2017, includes deferrals of previously incurred integration costs as regulatory assets of $24 million, $8 million, $8 million, and $8 million at PHI, Pepco, DPL and ACE, respectively. For the year ended December 31, 2016, includes deferrals of previously incurred integration costs as regulatory assets of $8 million, $6 million, $11 million and $4 million at ComEd, BGE, Pepco and DPL, respectively. For the Successor period March 24, 2016 to December 31, 2016, includes deferrals of previously incurred integration costs as regulatory assets of $16 million at PHI. See Note 4 - Regulatory Matters for additional information. |
Mergers, Acquisitions and Di_10
Mergers, Acquisitions and Dispositions Proforma Impact of Merger (Details) - USD ($) $ / shares in Units, $ in Millions | 12 Months Ended | |||||
Dec. 31, 2018 | [3] | Dec. 31, 2017 | Dec. 31, 2016 | |||
Business Acquisition, Pro Forma Revenue | $ 32,342 | [1] | $ 33,823 | [2] | ||
Business Acquisition, Pro Forma Net Income (Loss) | $ 1,562 | [1] | $ 2,618 | [2] | ||
Business Acquisition, Pro Forma Earnings Per Share, Basic | $ 1.69 | [1] | $ 2.85 | [2] | ||
Business Acquisition, Pro Forma Earnings Per Share, Diluted | $ 1.69 | [1] | $ 2.84 | [2] | ||
Noncash Merger Related Costs | $ 0 | $ 0 | [4] | $ 558 | [5],[6] | |
Consolidation, Eliminations [Member] | ||||||
Business Acquisition, Pro Forma Revenue | 171 | 559 | ||||
Noncash Merger Related Costs | $ 680 | $ 92 | ||||
[1] | The amounts above exclude non-recurring costs directly related to the merger of $680 million and intercompany revenue of $171 million for the year ended | |||||
[2] | The amounts above exclude non-recurring costs directly related to the merger of $92 million and intercompany revenue of $559 million for the year ended | |||||
[3] | See Note 5 - Mergers, Acquisitions and Dispositions for additional information. | |||||
[4] | See Note 5 - Mergers, Acquisitions and Dispositions for additional information. | |||||
[5] | Excludes $5 million of forgiveness of Accounts receivable related to merger commitments recorded in connection with the PHI Merger, the balance is included within Provision for uncollectible accounts. | |||||
[6] | See Note 5 - Mergers, Acquisitions and Dispositions for additional information. |
Property, Plant and Equipment P
Property, Plant and Equipment Property, Plant and Equipment - Summary of Property, Plant and Equipment (Details) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | |||
Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 99,609 | $ 95,266 | |||
Less: accumulated depreciation | [1] | 22,902 | 21,064 | ||
Property, plant and equipment, net | 76,707 | 74,202 | |||
Impairment of Long-Lived Assets Held-for-use | 50 | 573 | $ 306 | ||
Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 53,090 | 49,506 | |||
Electric—transmission and distribution | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Electric—transmission and distribution | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 90 years | ||||
Electric—generation | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 29,170 | 29,019 | |||
Electric—generation | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 1 year | ||||
Electric—generation | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 56 years | ||||
Gas Distribution Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 5,530 | 5,050 | |||
Gas Distribution Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Gas Distribution Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 90 years | ||||
Common—electric and gas | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 1,627 | 1,447 | |||
Common—electric and gas | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Common—electric and gas | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 75 years | ||||
Nuclear Fuel [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [2] | $ 5,957 | 6,420 | ||
Nuclear Fuel [Member] | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 1 year | ||||
Nuclear Fuel [Member] | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 8 years | ||||
Construction work in progress | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 3,377 | 2,825 | |||
Other Property Plant and Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [3] | $ 858 | 999 | ||
Other Property Plant and Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 1 year | ||||
Other Property Plant and Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 50 years | ||||
Exelon Generation Co L L C [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 36,187 | 36,334 | |||
Less: accumulated depreciation | [4] | 12,206 | 11,428 | ||
Property, plant and equipment, net | 23,981 | 24,906 | |||
Nuclear fuel - work in progress | 1,004 | 1,196 | |||
Capital Leases, Balance Sheet, Assets by Major Class, Net | 5 | 7 | |||
Capital Leased Assets, Gross | 47 | 47 | |||
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation | 42 | 40 | |||
Impairment of Long-Lived Assets Held-for-use | 50 | 510 | 243 | ||
Exelon Generation Co L L C [Member] | Electric—generation | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 29,170 | 29,019 | |||
Exelon Generation Co L L C [Member] | Electric—generation | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 1 year | ||||
Exelon Generation Co L L C [Member] | Electric—generation | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 56 years | ||||
Exelon Generation Co L L C [Member] | Nuclear Fuel [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [5] | $ 5,957 | 6,420 | ||
Less: accumulated depreciation | $ 2,969 | 3,159 | |||
Exelon Generation Co L L C [Member] | Nuclear Fuel [Member] | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 1 year | ||||
Exelon Generation Co L L C [Member] | Nuclear Fuel [Member] | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 8 years | ||||
Exelon Generation Co L L C [Member] | Construction work in progress | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 997 | 838 | |||
Exelon Generation Co L L C [Member] | Other Property Plant and Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [6] | $ 63 | 57 | ||
Exelon Generation Co L L C [Member] | Other Property Plant and Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 1 year | ||||
Exelon Generation Co L L C [Member] | Other Property Plant and Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 8 years | ||||
Commonwealth Edison Co [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 26,742 | 24,992 | |||
Less: accumulated depreciation | 4,684 | 4,269 | |||
Property, plant and equipment, net | 22,058 | 20,723 | |||
Capital Leases, Balance Sheet, Assets by Major Class, Net | 7 | 7 | |||
Capital Leased Assets, Gross | 8 | 8 | |||
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation | 1 | 1 | |||
Plant Held for Future Use Amount | 39 | ||||
Commonwealth Edison Co [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 25,991 | 24,423 | |||
Commonwealth Edison Co [Member] | Electric—transmission and distribution | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Commonwealth Edison Co [Member] | Electric—transmission and distribution | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 80 years | ||||
Commonwealth Edison Co [Member] | Construction work in progress | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 705 | 517 | |||
Commonwealth Edison Co [Member] | Other Property Plant and Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [7],[8] | $ 46 | 52 | ||
Commonwealth Edison Co [Member] | Other Property Plant and Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 35 years | ||||
Commonwealth Edison Co [Member] | Other Property Plant and Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 50 years | ||||
PECO Energy Co [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 12,171 | 11,464 | |||
Less: accumulated depreciation | 3,561 | 3,411 | |||
Property, plant and equipment, net | 8,610 | 8,053 | |||
Plant Held for Future Use Amount | 19 | ||||
PECO Energy Co [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 8,359 | 7,975 | |||
PECO Energy Co [Member] | Electric—transmission and distribution | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
PECO Energy Co [Member] | Electric—transmission and distribution | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 65 years | ||||
PECO Energy Co [Member] | Gas Distribution Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 2,694 | 2,504 | |||
PECO Energy Co [Member] | Gas Distribution Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
PECO Energy Co [Member] | Gas Distribution Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 70 years | ||||
PECO Energy Co [Member] | Common—electric and gas | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 756 | 710 | |||
PECO Energy Co [Member] | Common—electric and gas | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
PECO Energy Co [Member] | Common—electric and gas | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 50 years | ||||
PECO Energy Co [Member] | Construction work in progress | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 343 | 254 | |||
PECO Energy Co [Member] | Other Property Plant and Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [9] | $ 19 | 21 | ||
Average Service Life (years) | 50 years | ||||
Baltimore Gas and Electric Company [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 11,876 | 11,007 | |||
Less: accumulated depreciation | 3,633 | 3,405 | |||
Property, plant and equipment, net | 8,243 | 7,602 | |||
Plant Held for Future Use Amount | 25 | ||||
Impairment of Long-Lived Assets Held-for-use | 0 | 7 | 52 | ||
Baltimore Gas and Electric Company [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 7,951 | 7,464 | |||
Baltimore Gas and Electric Company [Member] | Electric—transmission and distribution | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Baltimore Gas and Electric Company [Member] | Electric—transmission and distribution | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 90 years | ||||
Baltimore Gas and Electric Company [Member] | Gas Distribution Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 2,630 | 2,379 | |||
Baltimore Gas and Electric Company [Member] | Gas Distribution Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Baltimore Gas and Electric Company [Member] | Gas Distribution Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 90 years | ||||
Baltimore Gas and Electric Company [Member] | Common—electric and gas | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 860 | 771 | |||
Baltimore Gas and Electric Company [Member] | Common—electric and gas | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Baltimore Gas and Electric Company [Member] | Common—electric and gas | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 40 years | ||||
Baltimore Gas and Electric Company [Member] | Construction work in progress | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 410 | 367 | |||
Baltimore Gas and Electric Company [Member] | Other Property Plant and Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [10] | $ 25 | 26 | ||
Average Service Life (years) | 20 years | ||||
Pepco Holdings LLC [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 14,287 | 12,985 | |||
Less: accumulated depreciation | 841 | 487 | |||
Property, plant and equipment, net | 13,446 | 12,498 | |||
Impairment of Long-Lived Assets Held-for-use | 0 | 52 | |||
Pepco Holdings LLC [Member] | Successor [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Impairment of Long-Lived Assets Held-for-use | $ 0 | ||||
Pepco Holdings LLC [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 12,664 | 11,517 | |||
Pepco Holdings LLC [Member] | Electric—transmission and distribution | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Pepco Holdings LLC [Member] | Electric—transmission and distribution | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 75 years | ||||
Pepco Holdings LLC [Member] | Gas Distribution Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 486 | 449 | |||
Pepco Holdings LLC [Member] | Gas Distribution Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Pepco Holdings LLC [Member] | Gas Distribution Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 75 years | ||||
Pepco Holdings LLC [Member] | Common—electric and gas | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 126 | 82 | |||
Pepco Holdings LLC [Member] | Common—electric and gas | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Pepco Holdings LLC [Member] | Common—electric and gas | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 75 years | ||||
Pepco Holdings LLC [Member] | Construction work in progress | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 912 | 835 | |||
Pepco Holdings LLC [Member] | Other Property Plant and Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [11] | $ 99 | 102 | ||
Pepco Holdings LLC [Member] | Other Property Plant and Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 3 years | ||||
Pepco Holdings LLC [Member] | Other Property Plant and Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 43 years | ||||
Potomac Electric Power Company [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 9,814 | 9,178 | |||
Less: accumulated depreciation | 3,354 | 3,177 | |||
Property, plant and equipment, net | 6,460 | 6,001 | |||
Plant Held for Future Use Amount | 61 | ||||
Impairment of Long-Lived Assets Held-for-use | 0 | 14 | 0 | ||
Potomac Electric Power Company [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 9,217 | 8,646 | |||
Potomac Electric Power Company [Member] | Electric—transmission and distribution | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Potomac Electric Power Company [Member] | Electric—transmission and distribution | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 75 years | ||||
Potomac Electric Power Company [Member] | Construction work in progress | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 536 | 473 | |||
Potomac Electric Power Company [Member] | Other Property Plant and Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [12] | $ 61 | 59 | ||
Potomac Electric Power Company [Member] | Other Property Plant and Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 25 years | ||||
Potomac Electric Power Company [Member] | Other Property Plant and Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 33 years | ||||
Delmarva Power & Light Company [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 5,150 | 4,826 | |||
Less: accumulated depreciation | 1,329 | 1,247 | |||
Property, plant and equipment, net | 3,821 | 3,579 | |||
Plant Held for Future Use Amount | 17 | ||||
Impairment of Long-Lived Assets Held-for-use | 0 | 6 | 0 | ||
Delmarva Power & Light Company [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 4,195 | 3,875 | |||
Delmarva Power & Light Company [Member] | Electric—transmission and distribution | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Delmarva Power & Light Company [Member] | Electric—transmission and distribution | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 70 years | ||||
Delmarva Power & Light Company [Member] | Gas Distribution Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 651 | 614 | |||
Delmarva Power & Light Company [Member] | Gas Distribution Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Delmarva Power & Light Company [Member] | Gas Distribution Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 75 years | ||||
Delmarva Power & Light Company [Member] | Common—electric and gas | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 136 | 117 | |||
Delmarva Power & Light Company [Member] | Common—electric and gas | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Delmarva Power & Light Company [Member] | Common—electric and gas | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 75 years | ||||
Delmarva Power & Light Company [Member] | Construction work in progress | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 151 | 205 | |||
Delmarva Power & Light Company [Member] | Other Property Plant and Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [13] | $ 17 | 15 | ||
Delmarva Power & Light Company [Member] | Other Property Plant and Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 10 years | ||||
Delmarva Power & Light Company [Member] | Other Property Plant and Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 43 years | ||||
Atlantic City Electric Company [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 4,103 | 3,772 | |||
Less: accumulated depreciation | 1,137 | 1,066 | |||
Property, plant and equipment, net | 2,966 | 2,706 | |||
Plant Held for Future Use Amount | 28 | ||||
Impairment of Long-Lived Assets Held-for-use | 0 | 7 | $ 0 | ||
Atlantic City Electric Company [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 3,866 | 3,607 | |||
Atlantic City Electric Company [Member] | Electric—transmission and distribution | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 5 years | ||||
Atlantic City Electric Company [Member] | Electric—transmission and distribution | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 60 years | ||||
Atlantic City Electric Company [Member] | Construction work in progress | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | $ 209 | 138 | |||
Atlantic City Electric Company [Member] | Other Property Plant and Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Total property, plant and equipment | [14] | $ 28 | $ 27 | ||
Atlantic City Electric Company [Member] | Other Property Plant and Equipment | Minimum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 13 years | ||||
Atlantic City Electric Company [Member] | Other Property Plant and Equipment | Maximum [Member] | |||||
Property, Plant and Equipment [Line Items] | |||||
Average Service Life (years) | 15 years | ||||
[1] | Includes accumulated amortization of nuclear fuel in the reactor core at Generation of $2,969 million and $3,159 million as of December 31, 2018 and 2017, respectively. | ||||
[2] | Includes nuclear fuel that is in the fabrication and installation phase of $1,004 million and $1,196 million at December 31, 2018 and 2017, respectively. | ||||
[3] | Includes Generation’s buildings under capital lease with a net carrying value of $5 million and $7 million at December 31, 2018 and 2017, respectively. The original cost basis of the buildings was $47 million as of both December 31, 2018 and 2017, and total accumulated amortization was $42 million and $40 million, as of December 31, 2018 and 2017, respectively. Also includes ComEd’s buildings under capital lease with a net carrying value at both December 31, 2018 and 2017 of $7 million. The original cost basis of the buildings was $8 million and total accumulated amortization was $1 million as of both December 31, 2018 and 2017. Includes land held for future use and non-utility property at ComEd, PECO, BGE, Pepco, DPL and ACE of $39 million, $19 million, $25 million, $61 million, $17 million and $28 million, respectively, at December 31, 2018. | ||||
[4] | Includes accumulated amortization of nuclear fuel in the reactor core of $2,969 million and $3,159 million as of December 31, 2018 and 2017, respectively | ||||
[5] | Includes nuclear fuel that is in the fabrication and installation phase of $1,004 million and $1,196 million at December 31, 2018 and 2017, respectively | ||||
[6] | Includes buildings under capital lease with a net carrying value of $5 million and $7 million at December 31, 2018 and 2017, respectively. The original cost basis of the buildings was $47 million as of both December 31, 2018 and 2017, and total accumulated amortization was $42 million and $40 million, as of December 31, 2018 and 2017, respectively. | ||||
[7] | Includes buildings under capital lease with a net carrying value at both December 31, 2018 and 2017 of $7 million. The original cost basis of the buildings was $8 million and total accumulated amortization was $1 million as of both December 31, 2018 and 2017 | ||||
[8] | Represents land held for future use and non-utility property. | ||||
[9] | Represents land held for future use and non-utility property. | ||||
[10] | Represents plant held for future use and non-utility property | ||||
[11] | Represents plant held for future use and non-utility property. | ||||
[12] | Represents plant held for future use and non-utility property. | ||||
[13] | Represents plant held for future use and non-utility property. | ||||
[14] | Represents plant held for future use and non-utility property. |
Property, Plant and Equipment_2
Property, Plant and Equipment Property, Plant and Equipment- Annual Depreciation Provisions as Percentage of Average Service Life (Details) | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.73% | 2.75% | 2.73% | ||
Electric—generation | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 5.37% | [1] | 4.36% | [1] | 5.94% |
Gas Distribution Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.07% | 2.10% | 2.17% | ||
Common—electric and gas | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 6.98% | 7.05% | 7.41% | ||
PECO Energy Co [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.35% | 2.37% | 2.32% | ||
PECO Energy Co [Member] | Gas Distribution Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 1.90% | 1.89% | 1.82% | ||
PECO Energy Co [Member] | Common—electric and gas | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 5.44% | 5.47% | 5.11% | ||
Baltimore Gas and Electric Company [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.61% | 2.58% | 2.56% | ||
Baltimore Gas and Electric Company [Member] | Gas Distribution Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.36% | 2.33% | 2.45% | ||
Baltimore Gas and Electric Company [Member] | Common—electric and gas | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 8.50% | 8.64% | 9.45% | ||
Pepco Holdings LLC [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.61% | 2.63% | 2.52% | ||
Pepco Holdings LLC [Member] | Gas Distribution Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 1.59% | 2.07% | 2.57% | ||
Pepco Holdings LLC [Member] | Common—electric and gas | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 6.30% | 6.50% | 8.12% | ||
Delmarva Power & Light Company [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.77% | 2.75% | 2.49% | ||
Delmarva Power & Light Company [Member] | Gas Distribution Equipment | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 1.59% | 2.07% | 2.57% | ||
Delmarva Power & Light Company [Member] | Common—electric and gas | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 3.70% | 4.14% | 4.99% | ||
[1] | See Note 8 — Early Plant Retirements for additional information on the accelerated net depreciation and amortization of Clinton, Quad Cities, Oyster Creek and TMI. |
Property, Plant and Equipment_3
Property, Plant and Equipment Property, Plant and Equipment- Narrative (Details) | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Electric—generation | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 5.37% | [1] | 4.36% | [1] | 5.94% |
Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.73% | 2.75% | 2.73% | ||
Exelon Generation Co L L C [Member] | Electric—generation | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 5.37% | 4.36% | 5.94% | ||
Commonwealth Edison Co [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.95% | 2.99% | 3.03% | ||
Potomac Electric Power Company [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.40% | 2.35% | 2.17% | ||
Atlantic City Electric Company [Member] | Electric—transmission and distribution | |||||
Property, Plant and Equipment [Line Items] | |||||
Annual depreciation rate | 2.45% | 2.46% | 2.45% | ||
[1] | See Note 8 — Early Plant Retirements for additional information on the accelerated net depreciation and amortization of Clinton, Quad Cities, Oyster Creek and TMI. |
Property, Plant and Equipment_4
Property, Plant and Equipment Property, Plant and Equipment - Summary of Capitalized Software Costs (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Net | $ 810 | $ 834 | |||
Capitalized Computer Software, Amortization | 282 | 270 | $ 255 | ||
Exelon Generation Co L L C [Member] | |||||
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Net | 164 | 173 | |||
Capitalized Computer Software, Amortization | 78 | 73 | 72 | ||
Commonwealth Edison Co [Member] | |||||
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Net | 206 | 227 | |||
Capitalized Computer Software, Amortization | 79 | 73 | 62 | ||
PECO Energy Co [Member] | |||||
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Net | 98 | 111 | |||
Capitalized Computer Software, Amortization | 37 | 39 | 33 | ||
Baltimore Gas and Electric Company [Member] | |||||
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Net | 166 | 179 | |||
Capitalized Computer Software, Amortization | 48 | 46 | 44 | ||
Potomac Electric Power Company [Member] | |||||
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Net | 26 | 2 | |||
Capitalized Computer Software, Amortization | 2 | 0 | 0 | ||
Pepco Holdings LLC [Member] | |||||
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Net | 165 | 133 | |||
Capitalized Computer Software, Amortization | 33 | 34 | |||
Delmarva Power & Light Company [Member] | |||||
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Net | 21 | 1 | |||
Capitalized Computer Software, Amortization | 2 | 0 | 0 | ||
Atlantic City Electric Company [Member] | |||||
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Net | 14 | 1 | |||
Capitalized Computer Software, Amortization | $ 1 | $ 0 | $ 0 | ||
Successor [Member] | Pepco Holdings LLC [Member] | |||||
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Amortization | $ 29 | ||||
Predecessor [Member] | Pepco Holdings LLC [Member] | |||||
Capitalized Software [Line Items] | |||||
Capitalized Computer Software, Amortization | $ 8 |
Property, Plant and Equipment_5
Property, Plant and Equipment Property, Plant and Equipment - Summary of Capitalized Interest and AFUDC (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | $ 1,695 | $ 1,658 | $ 1,678 | ||
Interest Costs Capitalized | 31 | 63 | 108 | |||
Allowance for Funds Used During Construction, Capitalized Interest | 109 | 108 | 98 | |||
Pepco Holdings LLC [Member] | ||||||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | 305 | 263 | |||
Allowance for Funds Used During Construction, Capitalized Interest | 44 | 54 | ||||
Exelon Generation Co L L C [Member] | ||||||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | 464 | 502 | 472 | ||
Interest Costs Capitalized | 31 | 63 | 107 | |||
Allowance for Funds Used During Construction, Capitalized Interest | 0 | 0 | 0 | |||
Commonwealth Edison Co [Member] | ||||||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | 377 | 369 | 469 | ||
Interest Costs Capitalized | 0 | 0 | 0 | |||
Allowance for Funds Used During Construction, Capitalized Interest | 30 | 20 | 22 | |||
PECO Energy Co [Member] | ||||||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | 141 | 130 | 127 | ||
Interest Costs Capitalized | 0 | 0 | 0 | |||
Allowance for Funds Used During Construction, Capitalized Interest | 12 | 12 | 11 | |||
Baltimore Gas and Electric Company [Member] | ||||||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | 130 | 111 | 114 | ||
Interest Costs Capitalized | 0 | 0 | 0 | |||
Allowance for Funds Used During Construction, Capitalized Interest | 24 | 22 | 30 | |||
Potomac Electric Power Company [Member] | ||||||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | 162 | 133 | 137 | ||
Interest Costs Capitalized | 0 | 0 | 0 | |||
Allowance for Funds Used During Construction, Capitalized Interest | 34 | 34 | 29 | |||
Delmarva Power & Light Company [Member] | ||||||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | 62 | 54 | 52 | ||
Interest Costs Capitalized | 0 | 0 | 0 | |||
Allowance for Funds Used During Construction, Capitalized Interest | 4 | 10 | 7 | |||
Atlantic City Electric Company [Member] | ||||||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | 68 | 64 | 65 | ||
Interest Costs Capitalized | 0 | 0 | 0 | |||
Allowance for Funds Used During Construction, Capitalized Interest | $ 4 | $ 9 | $ 9 | |||
Successor [Member] | Pepco Holdings LLC [Member] | ||||||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | $ 207 | ||||
Allowance for Funds Used During Construction, Capitalized Interest | $ 35 | |||||
Predecessor [Member] | Pepco Holdings LLC [Member] | ||||||
Capitalized Interest And AFUDC [Line Items] | ||||||
Interest Costs Incurred | [1] | $ 68 | ||||
Allowance for Funds Used During Construction, Capitalized Interest | $ 10 | |||||
[1] | Includes interest expense to affiliates. |
Impairment of Long-lived Asse_2
Impairment of Long-lived Assets Impairment of Long-Lived Assets - Narrative (Details) - USD ($) $ in Millions | 1 Months Ended | 3 Months Ended | 9 Months Ended | ||||||||
Mar. 31, 2016 | Jun. 30, 2018 | Jun. 30, 2017 | Sep. 30, 2016 | Jun. 30, 2016 | Mar. 31, 2016 | Sep. 30, 2017 | Dec. 31, 2018 | Sep. 30, 2018 | Dec. 31, 2017 | Sep. 30, 2015 | |
Capital Leases Net Investment In Direct Financing Leases [Line Items] | |||||||||||
Tangible Asset Impairment Charges | $ 36 | ||||||||||
Property, plant and equipment, net | $ 76,707 | $ 74,202 | |||||||||
Gain (Loss) on Contract Termination | $ 4 | ||||||||||
Finite-Lived Intangible Assets, Gross | 1,267 | 1,228 | |||||||||
Estimated residual value of leased assets | $ 356 | 356 | |||||||||
Proceeds From Lease Termination | $ 360 | ||||||||||
Wind Assets [Member] | |||||||||||
Capital Leases Net Investment In Direct Financing Leases [Line Items] | |||||||||||
Property, plant and equipment, net | 60 | ||||||||||
Property, Plant, and Equipment, Fair Value Disclosure | $ 24 | ||||||||||
Pepco Holdings LLC [Member] | |||||||||||
Capital Leases Net Investment In Direct Financing Leases [Line Items] | |||||||||||
Impairment of Long-Lived Assets to be Disposed of | $ 25 | ||||||||||
Property, plant and equipment, net | 13,446 | 12,498 | |||||||||
Finite-Lived Intangible Assets, Gross | $ 25 | ||||||||||
Exelon Generation Co L L C [Member] | |||||||||||
Capital Leases Net Investment In Direct Financing Leases [Line Items] | |||||||||||
Property, plant and equipment, net | $ 23,981 | $ 24,906 | |||||||||
Constellation Energy Group LLC [Member] | |||||||||||
Capital Leases Net Investment In Direct Financing Leases [Line Items] | |||||||||||
Tangible Asset Impairment Charges | $ 119 | $ 15 | |||||||||
Electricity Generation Plant, Non-Nuclear [Member] | |||||||||||
Capital Leases Net Investment In Direct Financing Leases [Line Items] | |||||||||||
Impaired Assets to be Disposed of by Method Other than Sale, Carrying Value of Asset | $ 41 | ||||||||||
Impairment of Long-Lived Assets to be Disposed of | $ 41 | $ 460 | $ 460 |
Early Plant Retirements Early_3
Early Plant Retirements Early Plant Retirements - Narrative (Details) - USD ($) $ in Millions | Oct. 01, 2018 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 |
Property, Plant and Equipment [Line Items] | ||||
Payments to Acquire Businesses, Gross | $ 154 | $ 208 | $ 6,923 | |
Exelon Generation Co L L C [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Payments to Acquire Businesses, Gross | $ 154 | $ 208 | $ 293 | |
Exelon Generation Co L L C [Member] | Nuclear Plant [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Ownership interest | 42.59% | |||
Everett Marine Terminal [Member] | Exelon Generation Co L L C [Member] | ||||
Property, Plant and Equipment [Line Items] | ||||
Payments to Acquire Businesses, Gross | $ 81 | |||
Business Combination, Separately Recognized Transactions, Net Gains and Losses | $ 75 |
Early Plant Retirements Early_4
Early Plant Retirements Early Plant Retirements - Pretax Expense (Details) - USD ($) $ in Millions | Dec. 17, 2016 | Jun. 16, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Property, Plant and Equipment [Line Items] | |||||||
Other, net | $ (112) | $ 947 | $ 297 | ||||
Facility Closing [Member] | TMOysterCreek [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Restructuring Reserve, Accelerated Depreciation | [1],[2] | 539 | |||||
Nuclear Fuel Amortization | [1] | 57 | |||||
Other Cost and Expense, Operating | [1],[3] | 32 | |||||
Accretion Expense, Including Asset Retirement Obligations | [1] | 0 | |||||
Other, net | [1] | 0 | |||||
Other Expenses | [1] | 628 | |||||
Facility Closing [Member] | Three Mile Island [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Restructuring Reserve, Accelerated Depreciation | [2],[4] | 250 | |||||
Nuclear Fuel Amortization | [4] | 12 | |||||
Other Cost and Expense, Operating | [3],[4] | 77 | |||||
Accretion Expense, Including Asset Retirement Obligations | [4] | 0 | |||||
Other, net | [4] | 0 | |||||
Other Expenses | [4] | 339 | |||||
Facility Closing [Member] | Clinton and Quad Cities [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Restructuring Reserve, Accelerated Depreciation | [2],[5] | 712 | |||||
Nuclear Fuel Amortization | [5] | 60 | |||||
Other Cost and Expense, Operating | $ (120) | $ 146 | 26 | [3],[5],[6] | |||
Accretion Expense, Including Asset Retirement Obligations | [5],[7] | 2 | |||||
Other, net | [5],[7] | (86) | |||||
Other Expenses | [5] | 714 | |||||
Exelon Generation Co L L C [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Other, net | (178) | 948 | 401 | ||||
Exelon Generation Co L L C [Member] | Facility Closing [Member] | TMOysterCreek [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Restructuring Reserve, Accelerated Depreciation | [1],[2] | 539 | |||||
Nuclear Fuel Amortization | [1] | 57 | |||||
Other Cost and Expense, Operating | [1],[3] | 32 | |||||
Accretion Expense, Including Asset Retirement Obligations | [1] | 0 | |||||
Other, net | [1] | 0 | |||||
Other Expenses | [1] | $ 628 | |||||
Exelon Generation Co L L C [Member] | Facility Closing [Member] | Three Mile Island [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Restructuring Reserve, Accelerated Depreciation | [2],[4] | 250 | |||||
Nuclear Fuel Amortization | [4] | 12 | |||||
Other Cost and Expense, Operating | [3],[4] | 77 | |||||
Accretion Expense, Including Asset Retirement Obligations | [4] | 0 | |||||
Other, net | [4] | 0 | |||||
Other Expenses | [4] | $ 339 | |||||
Exelon Generation Co L L C [Member] | Facility Closing [Member] | Clinton and Quad Cities [Member] | |||||||
Property, Plant and Equipment [Line Items] | |||||||
Restructuring Reserve, Accelerated Depreciation | [2],[5] | 712 | |||||
Nuclear Fuel Amortization | [5] | 60 | |||||
Other Cost and Expense, Operating | $ (120) | $ 146 | 26 | [3],[5],[6] | |||
Accretion Expense, Including Asset Retirement Obligations | [5],[7] | 2 | |||||
Other, net | [5],[7] | (86) | |||||
Other Expenses | [5] | $ 714 | |||||
[1] | Reflects incremental accelerated depreciation for TMI and Oyster Creek. The Oyster Creek year-to-date amounts are from February 2, 2018 through September 17, 2018. | ||||||
[2] | Reflects incremental accelerated depreciation of plant assets, including any ARC. | ||||||
[3] | Primarily includes materials and supplies inventory reserve adjustments, employee related costs and CWIP impairments. Excludes the charge to Operating and maintenance expense from the ARO remeasurement due to the announced sale of Oyster Creek. See Note 5 — Mergers, Acquisitions and Dispositions for additional information. | ||||||
[4] | Reflects incremental charges for TMI including incremental accelerated depreciation and amortization from May 30, 2017 through December 31, 2017. | ||||||
[5] | Reflects incremental charges for Clinton and Quad Cities including incremental accelerated depreciation and amortization from June 2, 2016 through December 6, 2016. In December 2016, as a result of reversing its retirement decision for Clinton and Quad Cities, Exelon and Generation updated the expected economic useful life for both facilities, to 2027 for Clinton, commensurate with the end of the Illinois ZES, and to 2032 for Quad Cities, the end of its current operating license. Depreciation was therefore adjusted beginning December 7, 2016, to reflect these extended useful life estimates. | ||||||
[6] | In June 2016, as a result of the retirement decision for Clinton and Quad Cities, Exelon and Generation recognized one-time charges of $146 million. In December 2016, as a result of reversing its retirement decision for Clinton and Quad Cities, Exelon and Generation reversed approximately $120 million of these one-time charges initially recorded in June 2016. | ||||||
[7] | For Quad Cities based on the regulatory agreement with the ICC, decommissioning-related activities are offset within Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. The offset results in an equal adjustment to the noncurrent payables to ComEd at Generation and an adjustment to the regulatory liabilities at ComEd. Likewise, ComEd has recorded an equal noncurrent affiliate receivable from Generation and corresponding regulatory liability. |
Early Plant Retirements Early_5
Early Plant Retirements Early Plant Retirements - Implications of Potential Early Plant Retirement on Balance Sheet (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 |
Implications of Potential Early Plant Retirement [Line Items] | ||
Property, plant and equipment, net | $ 76,707 | $ 74,202 |
Exelon Generation Co L L C [Member] | ||
Implications of Potential Early Plant Retirement [Line Items] | ||
Property, plant and equipment, net | 23,981 | $ 24,906 |
Exelon Generation Co L L C [Member] | Salem [Member] | Facility Closing [Member] | ||
Implications of Potential Early Plant Retirement [Line Items] | ||
Inventory, Raw Materials and Supplies, Gross | 45 | |
Nuclear Fuel, Net of Amortization | 118 | |
Property, plant and equipment, net | 538 | |
Construction in Progress, Gross | 44 | |
Asset Retirement Obligation | (395) | |
Exelon Generation Co L L C [Member] | Mystic Generating Station [Member] | Facility Closing [Member] | ||
Implications of Potential Early Plant Retirement [Line Items] | ||
Inventory, Raw Materials and Supplies, Gross | 30 | |
Nuclear Fuel, Net of Amortization | 20 | |
Property, plant and equipment, net | 901 | |
Construction in Progress, Gross | 9 | |
Asset Retirement Obligation | $ (1) |
Jointly Owned Electric Utilit_3
Jointly Owned Electric Utility Plant - Ownership Interests in Jointly Owned Electric Plants and Transmission Facilities (Details) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018USD ($)Vmi | Dec. 31, 2017USD ($) | ||
Pennsylvania [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Miles of transmission voltage lines | mi | 127 | ||
Transmission line capacity | V | 500 | ||
Delaware And New Jersey [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Miles of transmission voltage lines | mi | 151.3 | ||
Transmission line capacity | V | 500 | ||
Conemaugh [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Transmission line capacity | V | 500 | ||
Substation capacity | V | 500 | ||
Delaware River Crossing [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Miles of transmission voltage lines | mi | 2.5 | ||
Transmission line capacity | V | 500 | ||
New Freedom Switching [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Transmission line capacity | V | 500 | ||
Electric Transmission [Member] | Pennsylvania [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Plant | [1],[2] | $ 28 | $ 27 |
Accumulated depreciation | [1],[2] | 16 | 15 |
Construction work in progress | [2] | 1 | 0 |
Electric Transmission [Member] | Delaware And New Jersey [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Plant | [1],[3] | 103 | 102 |
Accumulated depreciation | [1],[3] | 53 | 52 |
Construction work in progress | [3] | 0 | 0 |
Other Service [Member] | Other Locations [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Plant | [1],[4] | 15 | 15 |
Accumulated depreciation | [1],[4] | 13 | 13 |
Construction work in progress | [4] | $ 0 | 0 |
Exelon Generation Co L L C [Member] | Merrill Creek [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 44.24% | ||
Exelon Generation Co L L C [Member] | Nuclear Plant [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 42.59% | ||
Exelon Generation Co L L C [Member] | Nuclear Plant [Member] | Quad Cities [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 75.00% | ||
Plant | [1] | $ 1,131 | 1,074 |
Accumulated depreciation | [1] | 587 | 550 |
Construction work in progress | $ 13 | 35 | |
Exelon Generation Co L L C [Member] | Nuclear Plant [Member] | Peach Bottom [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 50.00% | ||
Plant | [1] | $ 1,451 | 1,417 |
Accumulated depreciation | [1] | 523 | 461 |
Construction work in progress | $ 15 | 18 | |
Exelon Generation Co L L C [Member] | Nuclear Plant [Member] | Salem [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | [5] | 42.59% | |
Plant | [1],[5] | $ 648 | 631 |
Accumulated depreciation | [1],[5] | 227 | 205 |
Construction work in progress | [5] | $ 44 | 33 |
Exelon Generation Co L L C [Member] | Nuclear Plant [Member] | Nine Mile Point [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 82.00% | ||
Plant | [1] | $ 910 | 839 |
Accumulated depreciation | [1] | 126 | 97 |
Construction work in progress | 56 | 55 | |
Exelon Generation Co L L C [Member] | Fossil Fuel Generation [Member] | Salem [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Plant | $ 3 | ||
Exelon Generation Co L L C [Member] | Fossil Fuel Generation [Member] | Wyman [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 5.89% | ||
Plant | [1] | $ 4 | 3 |
Accumulated depreciation | [1] | 3 | 3 |
Construction work in progress | $ 0 | $ 0 | |
PECO Energy Co [Member] | Pennsylvania [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 22.00% | ||
PECO Energy Co [Member] | Delaware And New Jersey [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 42.55% | ||
PECO Energy Co [Member] | Conemaugh [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 20.72% | ||
PECO Energy Co [Member] | Delaware River Crossing [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 42.55% | ||
Baltimore Gas and Electric Company [Member] | Pennsylvania [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 7.00% | ||
Baltimore Gas and Electric Company [Member] | Conemaugh [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 10.56% | ||
Potomac Electric Power Company [Member] | Pennsylvania [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 27.00% | ||
Potomac Electric Power Company [Member] | Conemaugh [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 9.72% | ||
Potomac Electric Power Company [Member] | Valley Forge [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 11.90% | ||
Delmarva Power & Light Company [Member] | Pennsylvania [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 9.00% | ||
Delmarva Power & Light Company [Member] | Delaware And New Jersey [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 1.00% | ||
Delmarva Power & Light Company [Member] | Conemaugh [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 3.72% | ||
Delmarva Power & Light Company [Member] | Delaware River Crossing [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 7.45% | ||
Delmarva Power & Light Company [Member] | Merrill Creek [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 11.91% | ||
Delmarva Power & Light Company [Member] | Valley Forge [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 7.40% | ||
Atlantic City Electric Company [Member] | Pennsylvania [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 8.00% | ||
Atlantic City Electric Company [Member] | Delaware And New Jersey [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 13.90% | ||
Atlantic City Electric Company [Member] | Conemaugh [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 3.83% | ||
Atlantic City Electric Company [Member] | Delaware River Crossing [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 7.45% | ||
Atlantic City Electric Company [Member] | Merrill Creek [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 4.83% | ||
Atlantic City Electric Company [Member] | Valley Forge [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 6.60% | ||
Atlantic City Electric Company [Member] | New Freedom Switching [Member] | |||
Schedule Of Jointly Owned Utility Plant Net Ownership [Abstract] | |||
Ownership interest | 21.78% | ||
[1] | Excludes asset retirement costs and general plant. | ||
[2] | PECO, BGE, Pepco, DPL and ACE own a 22%, 7%, 27%, 9% and 8% share, respectively, in 127 miles of 500kV lines located in Pennsylvania as well as a 20.72%, 10.56%, 9.72%, 3.72% and 3.83% share, respectively, of a 500kV substation immediately outside of the Conemaugh fossil-generating station which supplies power to the 500kV lines including, but not limited to, the lines noted above. | ||
[3] | PECO, DPL and ACE own a 42.55%, 1% and 13.9% share, respectively in 151.3 miles of 500kV lines located in New Jersey and of the Salem generating plant substation. PECO, DPL and ACE also own a 42.55%, 7.45% and 7.45% share, respectively, in 2.5 miles of 500kV line located over the Delaware River. ACE also has a 21.78% share in a 500kV New Freedom Switching | ||
[4] | Generation, DPL and ACE own a 44.24%, 11.91% and 4.83% share, respectively in assets located at Merrill Creek Reservoir located in New Jersey. Pepco, DPL and ACE own a 11.9%, 7.4% and 6.6% share, respectively, in Valley Forge Corporate Center. | ||
[5] | Generation also owns a proportionate share in the fossil-fuel combustion turbine at Salem, which is fully depreciated. The gross book value was $3 million at December 31, 2018 and 2017. |
Intangible Assets - Schedule of
Intangible Assets - Schedule of Goodwill (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Goodwill [Roll Forward] | |||
Goodwill, Gross | $ 8,660 | $ 8,660 | $ 8,660 |
Goodwill, beginning balance | 6,677 | 6,677 | |
Impairment losses | 0 | 0 | |
Goodwill, ending balance | 6,677 | 6,677 | |
Goodwill, Impaired, Accumulated Impairment Loss | 1,983 | 1,983 | 1,983 |
Exelon Generation Co L L C [Member] | |||
Goodwill [Roll Forward] | |||
Goodwill, beginning balance | 47 | ||
Goodwill, ending balance | 47 | 47 | |
Commonwealth Edison Co [Member] | |||
Goodwill [Roll Forward] | |||
Goodwill, Gross | 4,608 | 4,608 | 4,608 |
Goodwill, beginning balance | 2,625 | 2,625 | |
Impairment losses | 0 | 0 | |
Goodwill, ending balance | 2,625 | 2,625 | |
Goodwill, Impaired, Accumulated Impairment Loss | 1,983 | 1,983 | 1,983 |
Delmarva Power & Light Company [Member] | |||
Goodwill [Roll Forward] | |||
Goodwill, beginning balance | 8 | ||
Goodwill, ending balance | 8 | 8 | |
Pepco Holdings LLC [Member] | |||
Goodwill [Roll Forward] | |||
Goodwill, Gross | 4,005 | 4,005 | $ 4,005 |
Goodwill, beginning balance | 4,005 | 4,005 | |
Impairment losses | 0 | ||
Goodwill, ending balance | $ 4,005 | $ 4,005 |
Intangible Assets - Narrative (
Intangible Assets - Narrative (Details) - USD ($) $ in Millions | 12 Months Ended | ||||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Nov. 01, 2016 | Mar. 24, 2016 | |
Goodwill [Line Items] | |||||
Goodwill | $ 6,677 | $ 6,677 | $ 6,677 | ||
Amortization of Intangible Assets | (109) | (237) | (336) | ||
Exelon Generation Co L L C [Member] | |||||
Goodwill [Line Items] | |||||
Goodwill | 47 | 47 | |||
Amortization of Intangible Assets | 63 | 83 | 79 | ||
Commonwealth Edison Co [Member] | |||||
Goodwill [Line Items] | |||||
Goodwill | 2,625 | 2,625 | 2,625 | ||
Amortization of Intangible Assets | 7 | 7 | 7 | ||
Reporting Unit, Percentage of Fair Value in Excess of Carrying Amount | 30.00% | ||||
Pepco Holdings LLC [Member] | |||||
Goodwill [Line Items] | |||||
Goodwill | 4,005 | 4,005 | $ 4,005 | ||
Potomac Electric Power Company [Member] | |||||
Goodwill [Line Items] | |||||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets | $ 2,100 | ||||
Fresh-Start Adjustment, Increase (Decrease), Goodwill | 400 | ||||
Reporting Unit, Percentage of Fair Value in Excess of Carrying Amount | 30.00% | ||||
Delmarva Power & Light Company [Member] | |||||
Goodwill [Line Items] | |||||
Goodwill | $ 8 | $ 8 | |||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets | 1,400 | ||||
Fresh-Start Adjustment, Increase (Decrease), Goodwill | 300 | ||||
Reporting Unit, Percentage of Fair Value in Excess of Carrying Amount | 20.00% | ||||
Atlantic City Electric Company [Member] | |||||
Goodwill [Line Items] | |||||
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Indefinite-Lived Intangible Assets | 500 | ||||
Fresh-Start Adjustment, Increase (Decrease), Goodwill | $ (700) | ||||
Reporting Unit, Percentage of Fair Value in Excess of Carrying Amount | 30.00% | ||||
Constellation Energy Group LLC [Member] | Trade Names [Member] | |||||
Goodwill [Line Items] | |||||
Useful life | 10 years |
Intangible Assets - Schedule _2
Intangible Assets - Schedule of Other Intangible Assets (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2015 | |
Finite-Lived Intangible Assets [Line Items] | ||||
Gross | $ 1,267 | $ 1,228 | ||
Accumulated Amortization | (1,149) | (1,255) | ||
Net | 118 | (27) | ||
Finite-Lived Intangible Assets, Gross | 1,267 | 1,228 | ||
Exelon Enterprise [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
2,018 | [1] | (32) | ||
2,019 | [1] | (20) | ||
2,020 | [1] | (4) | ||
2,021 | [1] | (23) | ||
2,022 | [1] | (21) | ||
Exelon Enterprise [Member] | Licensing Agreements [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Gross | [1] | 95 | 95 | |
Accumulated Amortization | [1] | (34) | (25) | |
Net | [1] | 61 | 70 | |
Finite-Lived Intangible Assets, Gross | [1] | 95 | 95 | |
Exelon Generation Consolidated [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
2,018 | [1] | 70 | ||
2,019 | [1] | 78 | ||
2,020 | [1] | 78 | ||
2,021 | [1] | 56 | ||
2,022 | [1] | 50 | ||
Exelon Generation Co L L C [Member] | Unamortized Energy Contracts [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Gross | [2],[3] | 1,957 | 1,938 | |
Accumulated Amortization | [2],[3] | (1,588) | (1,574) | |
Net | [2],[3] | 369 | 364 | |
Finite-Lived Intangible Assets, Gross | [2],[3] | 1,957 | 1,938 | |
Exelon Generation Co L L C [Member] | Customer Relationships [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Gross | 325 | 305 | ||
Accumulated Amortization | (162) | (133) | ||
Net | 163 | 172 | ||
Finite-Lived Intangible Assets, Gross | 325 | 305 | ||
Exelon Generation Co L L C [Member] | Trade Names [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Gross | 243 | 243 | ||
Accumulated Amortization | (171) | (148) | ||
Net | 72 | 95 | ||
Finite-Lived Intangible Assets, Gross | 243 | 243 | ||
Commonwealth Edison Co [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
2,018 | [1] | 7 | ||
2,019 | [1] | 7 | ||
2,020 | [1] | 0 | ||
2,021 | [1] | 0 | ||
2,022 | [1] | 0 | ||
Commonwealth Edison Co [Member] | Intangible Asset Nineteen Ninety Nine Chicago Settlement Agreement [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Gross | 162 | 162 | ||
Accumulated Amortization | (148) | (141) | ||
Net | 14 | 21 | ||
Finite-Lived Intangible Assets, Gross | 162 | 162 | ||
PHI Service Co Affiliate [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
2,018 | [1] | (119) | ||
2,019 | [1] | (115) | ||
2,020 | [1] | (92) | ||
2,021 | [1] | (89) | ||
2,022 | [1] | (81) | ||
Pepco Holdings LLC [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Gross | $ 25 | |||
Finite-Lived Intangible Assets, Gross | $ 25 | |||
Pepco Holdings LLC [Member] | Unamortized Energy Contracts [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Gross | (1,515) | (1,515) | ||
Accumulated Amortization | 954 | 766 | ||
Net | (561) | (749) | ||
Finite-Lived Intangible Assets, Gross | $ (1,515) | $ (1,515) | ||
[1] | (a)On May 31, 2015, Exelon entered into a long-term software license agreement. Exelon is required to make payments starting August 2015 through May 2024. The intangible asset recognized as a result of these payments is being amortized on a straight-line basis over the contract term. | |||
[2] | (b)Includes unamortized energy contract assets and liabilities in Exelon's, Generations and PHI's Consolidated Balance Sheets. | |||
[3] | (c)In March 1999 and February 2003, ComEd entered into separate agreements with the City of Chicago and Midwest Generation, LLC. Under the terms of the settlement, ComEd agreed to make payments to the City of Chicago. The intangible asset recognized as a result of the settlement agreement is being amortized ratably over the remaining term of the City of Chicago franchise agreement. |
Intangible Assets - Summary of
Intangible Assets - Summary of Amortization Expense (Details) - USD ($) $ in Millions | 12 Months Ended | ||||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Mar. 24, 2016 | ||
Finite-Lived Intangible Assets [Line Items] | |||||
Intangible asset amortization expense | $ (109) | $ (237) | $ (336) | ||
Potomac Electric Power Company [Member] | |||||
Finite-Lived Intangible Assets [Line Items] | |||||
Fresh-Start Adjustment, Increase (Decrease), Goodwill | $ 400 | ||||
Exelon Generation Co L L C [Member] | |||||
Finite-Lived Intangible Assets [Line Items] | |||||
Intangible asset amortization expense | 63 | 83 | 79 | ||
Commonwealth Edison Co [Member] | |||||
Finite-Lived Intangible Assets [Line Items] | |||||
Intangible asset amortization expense | 7 | 7 | 7 | ||
PHI Service Co Affiliate [Member] | |||||
Finite-Lived Intangible Assets [Line Items] | |||||
Intangible asset amortization expense | (188) | (336) | (430) | ||
Delmarva Power & Light Company [Member] | |||||
Finite-Lived Intangible Assets [Line Items] | |||||
Fresh-Start Adjustment, Increase (Decrease), Goodwill | $ 300 | ||||
Unamortized Energy Contracts [Member] | |||||
Finite-Lived Intangible Assets [Line Items] | |||||
Amortization of Power Contracts Emission Credits | [1] | 14 | 35 | 35 | |
Unamortized Energy Contracts [Member] | Exelon Generation Co L L C [Member] | |||||
Finite-Lived Intangible Assets [Line Items] | |||||
Amortization of Power Contracts Emission Credits | [1] | $ 14 | $ 35 | $ 35 | |
[1] | Included in Operating revenues or Purchased power and fuel in the Registrants’ Consolidated Statements of Operations and Comprehensive Income |
Intangible Assets Renewable and
Intangible Assets Renewable and Alternative Energy Credits (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2015 | |
Finite-Lived Intangible Assets [Line Items] | ||||
Finite-Lived Intangible Assets, Gross | $ 1,267 | $ 1,228 | ||
Finite-Lived Intangible Assets, Accumulated Amortization | 1,149 | 1,255 | ||
Finite-Lived Intangible Assets, Net | 118 | (27) | ||
Exelon Generation Co L L C [Member] | Alternative energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 0 | 0 | ||
Exelon Generation Co L L C [Member] | Renewable energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 270 | 312 | ||
Exelon Generation Co L L C [Member] | Renewable energy credit noncurrent [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 52 | 27 | ||
Exelon Consolidations [Member] | Alternative energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 2 | 1 | ||
Exelon Consolidations [Member] | Renewable energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 279 | 321 | ||
Exelon Consolidations [Member] | Renewable energy credit noncurrent [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 52 | 27 | ||
PECO Energy Co [Member] | Alternative energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 2 | 1 | ||
PECO Energy Co [Member] | Renewable energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 0 | 0 | ||
PECO Energy Co [Member] | Renewable energy credit noncurrent [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 0 | 0 | ||
Pepco Holdings LLC [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Finite-Lived Intangible Assets, Gross | $ 25 | |||
Pepco Holdings LLC [Member] | Alternative energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 0 | 0 | ||
Pepco Holdings LLC [Member] | Renewable energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 9 | 9 | ||
Pepco Holdings LLC [Member] | Renewable energy credit noncurrent [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 0 | 0 | ||
Exelon Enterprise [Member] | Licensing Agreements [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Finite-Lived Intangible Assets, Gross | [1] | 95 | 95 | |
Finite-Lived Intangible Assets, Accumulated Amortization | [1] | 34 | 25 | |
Finite-Lived Intangible Assets, Net | [1] | 61 | 70 | |
Delmarva Power & Light Company [Member] | Alternative energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 0 | 0 | ||
Delmarva Power & Light Company [Member] | Renewable energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 8 | 8 | ||
Delmarva Power & Light Company [Member] | Renewable energy credit noncurrent [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 0 | 0 | ||
Atlantic City Electric Company [Member] | Alternative energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 0 | 0 | ||
Atlantic City Electric Company [Member] | Renewable energy credit current [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | 1 | 1 | ||
Atlantic City Electric Company [Member] | Renewable energy credit noncurrent [Member] | ||||
Finite-Lived Intangible Assets [Line Items] | ||||
Acquired Finite-lived Intangible Asset, Residual Value | $ 0 | $ 0 | ||
[1] | (a)On May 31, 2015, Exelon entered into a long-term software license agreement. Exelon is required to make payments starting August 2015 through May 2024. The intangible asset recognized as a result of these payments is being amortized on a straight-line basis over the contract term. |
Fair Value of Financial Asset_3
Fair Value of Financial Assets and Liabilities Fair Value of Financial Assets and Liabilities - Fair Value of Financial Liabilities Recorded at the Carrying Amount (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | $ 795 | $ 865 | |
Spent Nuclear Fuel Obligation, Noncurrent | 1,171 | 1,147 | |
Debt Issuance Costs, Net | 216 | 201 | |
Financing Trust Member [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Debt Issuance Costs, Net | 0 | (1) | |
Estimate of Fair Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 714 | 929 | |
Long-term debt (including amounts due within one year)(a) | [1] | 35,869 | 36,705 |
Due to Related Parties, Noncurrent | [2] | 400 | 431 |
Spent Nuclear Fuel Obligation, Noncurrent | 949 | 936 | |
Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | 0 | |
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Due to Related Parties, Noncurrent | [2] | 0 | 0 |
Spent Nuclear Fuel Obligation, Noncurrent | 0 | 0 | |
Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 714 | 929 | |
Long-term debt (including amounts due within one year)(a) | [1] | 33,711 | 34,735 |
Due to Related Parties, Noncurrent | [2] | 0 | 0 |
Spent Nuclear Fuel Obligation, Noncurrent | 949 | 936 | |
Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | 0 | |
Long-term debt (including amounts due within one year)(a) | [1] | 2,158 | 1,970 |
Due to Related Parties, Noncurrent | [2] | 400 | 431 |
Spent Nuclear Fuel Obligation, Noncurrent | 0 | 0 | |
Reported Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 714 | 929 | |
Long-term debt (including amounts due within one year)(a) | [1] | 35,424 | 34,264 |
Due to Related Parties, Noncurrent | [2] | 390 | 389 |
Spent Nuclear Fuel Obligation, Noncurrent | 1,171 | 1,147 | |
Exelon Generation Co L L C [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | 91 | 103 | |
Spent Nuclear Fuel Obligation, Noncurrent | 1,171 | 1,147 | |
Debt Issuance Costs, Net | 51 | 60 | |
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 2 | ||
Long-term debt (including amounts due within one year)(a) | [1] | 8,910 | 9,512 |
Spent Nuclear Fuel Obligation, Noncurrent | 949 | 936 | |
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | ||
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Spent Nuclear Fuel Obligation, Noncurrent | 0 | 0 | |
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 2 | ||
Long-term debt (including amounts due within one year)(a) | [1] | 7,467 | 7,839 |
Spent Nuclear Fuel Obligation, Noncurrent | 949 | 936 | |
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | ||
Long-term debt (including amounts due within one year)(a) | [1] | 1,443 | 1,673 |
Spent Nuclear Fuel Obligation, Noncurrent | 0 | 0 | |
Exelon Generation Co L L C [Member] | Reported Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 2 | ||
Long-term debt (including amounts due within one year)(a) | [1] | 8,793 | 8,990 |
Spent Nuclear Fuel Obligation, Noncurrent | 1,171 | 1,147 | |
Commonwealth Edison Co [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Debt Issuance Costs, Net | 63 | 52 | |
Commonwealth Edison Co [Member] | Financing Trust Member [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Debt Issuance Costs, Net | (1) | (1) | |
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | [1] | 8,390 | 8,418 |
Due to Related Parties, Noncurrent | [2] | 209 | 227 |
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Due to Related Parties, Noncurrent | [2] | 0 | 0 |
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | [1] | 8,390 | 8,418 |
Due to Related Parties, Noncurrent | [2] | 0 | 0 |
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Due to Related Parties, Noncurrent | [2] | 209 | 227 |
Commonwealth Edison Co [Member] | Reported Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | [1] | 8,101 | 7,601 |
Due to Related Parties, Noncurrent | [2] | 205 | 205 |
PECO Energy Co [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Debt Issuance Costs, Net | 23 | 17 | |
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | [1] | 3,207 | 3,194 |
Due to Related Parties, Noncurrent | 191 | 204 | |
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Due to Related Parties, Noncurrent | 0 | 0 | |
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | [1] | 3,157 | 3,194 |
Due to Related Parties, Noncurrent | 0 | 0 | |
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | [1] | 50 | 0 |
Due to Related Parties, Noncurrent | 191 | 204 | |
PECO Energy Co [Member] | Reported Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | [1] | 3,084 | 2,903 |
Due to Related Parties, Noncurrent | 184 | 184 | |
Baltimore Gas and Electric Company [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Debt Issuance Costs, Net | 18 | 17 | |
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 35 | 77 | |
Long-term debt (including amounts due within one year)(a) | [1] | 2,950 | 2,825 |
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | 0 | |
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 35 | 77 | |
Long-term debt (including amounts due within one year)(a) | [1] | 2,950 | 2,825 |
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | 0 | |
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Baltimore Gas and Electric Company [Member] | Reported Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 35 | 77 | |
Long-term debt (including amounts due within one year)(a) | [1] | 2,876 | 2,577 |
Pepco Holdings LLC [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-term debt (including amounts due within one year)(a) | 633 | 686 | |
Pepco Holdings LLC [Member] | Successor [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Debt Issuance Costs, Net | 14 | 6 | |
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 179 | 350 | |
Long-term debt (including amounts due within one year)(a) | [1] | 6,101 | 6,019 |
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | 0 | |
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 179 | 350 | |
Long-term debt (including amounts due within one year)(a) | [1] | 5,436 | 5,722 |
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | 0 | |
Long-term debt (including amounts due within one year)(a) | [1] | 665 | 297 |
Pepco Holdings LLC [Member] | Reported Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 179 | 350 | |
Long-term debt (including amounts due within one year)(a) | [1] | 6,259 | 5,874 |
Potomac Electric Power Company [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Debt Issuance Costs, Net | 34 | 32 | |
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 40 | 26 | |
Long-term debt (including amounts due within one year)(a) | [1] | 3,097 | 3,123 |
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | 0 | |
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 40 | 26 | |
Long-term debt (including amounts due within one year)(a) | [1] | 2,901 | 3,114 |
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | 0 | |
Long-term debt (including amounts due within one year)(a) | [1] | 196 | 9 |
Potomac Electric Power Company [Member] | Reported Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 40 | 26 | |
Long-term debt (including amounts due within one year)(a) | [1] | 2,719 | 2,540 |
Delmarva Power & Light Company [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Debt Issuance Costs, Net | 12 | 11 | |
Delmarva Power & Light Company [Member] | Estimate of Fair Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 216 | ||
Long-term debt (including amounts due within one year)(a) | [1] | 1,496 | 1,393 |
Delmarva Power & Light Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | ||
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Delmarva Power & Light Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 216 | ||
Long-term debt (including amounts due within one year)(a) | [1] | 1,303 | 1,393 |
Delmarva Power & Light Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | ||
Long-term debt (including amounts due within one year)(a) | [1] | 193 | 0 |
Delmarva Power & Light Company [Member] | Reported Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 216 | ||
Long-term debt (including amounts due within one year)(a) | [1] | 1,494 | 1,300 |
Atlantic City Electric Company [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Debt Issuance Costs, Net | 7 | 5 | |
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 139 | 108 | |
Long-term debt (including amounts due within one year)(a) | [1] | 1,262 | 1,237 |
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | 0 | |
Long-term debt (including amounts due within one year)(a) | [1] | 0 | 0 |
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 139 | 108 | |
Long-term debt (including amounts due within one year)(a) | [1] | 987 | 949 |
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 0 | 0 | |
Long-term debt (including amounts due within one year)(a) | [1] | 275 | 288 |
Atlantic City Electric Company [Member] | Reported Value Measurement [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Short-term Debt, Fair Value | 139 | 108 | |
Long-term debt (including amounts due within one year)(a) | [1] | $ 1,188 | $ 1,121 |
[1] | Includes unamortized debt issuance costs which are not fair valued of $216 million, $51 million, $63 million, $23 million, $18 million, $14 million, $34 million, $12 million and $7 million for Exelon, Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE respectively, as of December 31, 2018. Includes unamortized debt issuance costs which are not fair valued of $201 million, $60 million, $52 million, $17 million, $17 million, $6 million, $32 million, $11 million and $5 million for Exelon, Generation, ComEd, PECO, BGE, PHI, Pepco, DPL and ACE respectively, as of December 31, 2017. | ||
[2] | Includes unamortized debt issuance costs which are not fair valued of $0 million and $1 million for Exelon and ComEd, respectively, as of December 31, 2018. Includes unamortized debt issuance costs which are not fair valued of $1 million and $1 million for Exelon and ComEd, respectively, as of December 31, 2017. |
Fair Value of Financial Asset_4
Fair Value of Financial Assets and Liabilities Fair Value of Financial Assets and Liabilities - Fair Value Measurement of Assets and Liabilities, Recurring and Nonrecurring (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Current | $ (475) | $ (232) | |
Derivative Liability, Noncurrent | (479) | (409) | |
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis [Abstract] | |||
Derivative, collateral, right to reclaim cash | 50 | 77 | |
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value | 44 | 1 | |
Derivative Asset, Notional Amount | 1,432 | 811 | |
Margin Deposit Assets | (94) | (117) | |
Cash and Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 458 | 389 | |
Restricted cash [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 80 | 145 | |
Other assets | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 185 | 85 | |
Nuclear Decommissioning Trust Fund Investments [Member] | |||
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis [Abstract] | |||
Fair Value Net Assets Liabilities Excluded From Nuclear Decommissioning Trust Fund Investments | (130) | (82) | |
Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [1] | 1,243 | 656 |
FinancialAssetsFairValueDisclosure1 | 15,618 | 15,716 | |
Deferred Compensation Liability, Current and Noncurrent | (137) | (145) | |
Financial Liabilities Fair Value Disclosure | (1,091) | (786) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 14,527 | 14,930 | |
Alternative Investment, Fair Value Disclosure | 3,433 | 3,534 | |
Fair Value, Measurements, Recurring [Member] | Commodity Derivative Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (947) | (637) | |
Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (4,881) | (4,040) | |
Fair Value, Measurements, Recurring [Member] | Proprietary Trading Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (94) | (53) | |
Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [2],[3] | 4,028 | 3,456 |
Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (7) | (4) | |
Fair Value, Measurements, Recurring [Member] | Derivatives Designated As Hedging Instruments Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (4) | (2) | |
Fair Value, Measurements, Recurring [Member] | EconomicHedgingInstrumentLiabilites1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (6) | (9) | |
Fair Value, Measurements, Recurring [Member] | Effect of Netting and Allocation of Collateral Interest Rate and FX Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 3 | 7 | |
Fair Value, Measurements, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [4] | 12,825 | 13,431 |
Alternative Investment, Fair Value Disclosure | [4] | 3,433 | 3,510 |
Fair Value, Measurements, Recurring [Member] | Cash Equivalents NDT [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [5] | 338 | 220 |
Fair Value, Measurements, Recurring [Member] | Equity Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 5,890 | 7,254 | |
Alternative Investment, Fair Value Disclosure | 1,381 | 2,176 | |
Fair Value, Measurements, Recurring [Member] | Fixed Income Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 5,078 | 4,736 | |
Alternative Investment, Fair Value Disclosure | 846 | 510 | |
Fair Value, Measurements, Recurring [Member] | Corporate Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 1,823 | 1,865 | |
Fair Value, Measurements, Recurring [Member] | US Treasury and Government [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 2,180 | 1,969 | |
Fair Value, Measurements, Recurring [Member] | Foreign Government Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 50 | 82 | |
Fair Value, Measurements, Recurring [Member] | State and municipal debt [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 149 | 263 | |
Fair Value, Measurements, Recurring [Member] | Other Fixed Income [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [6] | 876 | 557 |
Alternative Investment, Fair Value Disclosure | [6] | 846 | 510 |
Fair Value, Measurements, Recurring [Member] | Middle market lending [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 680 | 528 | |
Alternative Investment, Fair Value Disclosure | 367 | 131 | |
Fair Value, Measurements, Recurring [Member] | Private Equity Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 329 | 222 | |
Alternative Investment, Fair Value Disclosure | 329 | 222 | |
Fair Value, Measurements, Recurring [Member] | Real Estate Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 510 | 471 | |
Alternative Investment, Fair Value Disclosure | 510 | 471 | |
Fair Value, Measurements, Recurring [Member] | Pledged Assets For Zion Station Decommissioning [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 9 | 39 | |
Alternative Investment, Fair Value Disclosure | 0 | 24 | |
Fair Value, Measurements, Recurring [Member] | Cash Equivalent Zion [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 9 | 2 | |
Fair Value, Measurements, Recurring [Member] | Equity Funds Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 1 | |
Fair Value, Measurements, Recurring [Member] | MiddleMarketLending Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 36 | |
Alternative Investment, Fair Value Disclosure | 0 | 24 | |
Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 243 | 240 | |
Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 48 | 77 | |
Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 72 | 58 | |
Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 15 | 12 | |
Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 108 | 93 | |
Fair Value, Measurements, Recurring [Member] | Commodity Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 1,246 | 1,304 | |
Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 4,771 | 4,225 | |
Fair Value, Measurements, Recurring [Member] | Proprietary Trading [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 146 | 68 | |
Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | [2],[3] | (3,671) | (2,989) |
Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 10 | 9 | |
Fair Value, Measurements, Recurring [Member] | Designated as Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 6 | |
Fair Value, Measurements, Recurring [Member] | Economic hedge Interest and Currency [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 13 | 10 | |
Fair Value, Measurements, Recurring [Member] | EffectsofNettingandAllocationofCollateral1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | (3) | (7) | |
Fair Value, Measurements, Recurring [Member] | Other Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 42 | 37 | |
Fair Value, Inputs, Level 1 [Member] | |||
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis [Abstract] | |||
Derivative, Fair Value, Amount Offset Against Collateral, Net | 57 | 65 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [1] | 1,243 | 656 |
FinancialAssetsFairValueDisclosure1 | 6,582 | 6,980 | |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | (3) | (63) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 6,579 | 6,917 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (3) | (64) | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (642) | (713) | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | (2) | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [2],[3] | 639 | 651 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 1 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Derivatives Designated As Hedging Instruments Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | EconomicHedgingInstrumentLiabilites1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | (1) | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Effect of Netting and Allocation of Collateral Interest Rate and FX Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 2 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [4] | 5,251 | 6,215 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents NDT [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [5] | 252 | 135 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 2,918 | 4,163 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 2,081 | 1,917 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Corporate Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | US Treasury and Government [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 2,081 | 1,917 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Foreign Government Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | State and municipal debt [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Other Fixed Income [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [6] | 0 | 0 |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Middle market lending [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Private Equity Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Real Estate Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Pledged Assets For Zion Station Decommissioning [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 9 | 2 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalent Zion [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 9 | 2 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Funds Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | MiddleMarketLending Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 120 | 135 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 48 | 77 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 72 | 58 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | (41) | (26) | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 541 | 557 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 2 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | [2],[3] | (582) | (585) |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | (2) | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Designated as Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Economic hedge Interest and Currency [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | EffectsofNettingandAllocationofCollateral1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | (2) | |
Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Other Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | |||
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis [Abstract] | |||
Derivative, Fair Value, Amount Offset Against Collateral, Net | 224 | 320 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [1] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 4,165 | 3,793 | |
Deferred Compensation Liability, Current and Noncurrent | (137) | (145) | |
Financial Liabilities Fair Value Disclosure | (599) | (329) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 3,566 | 3,464 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (455) | (179) | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (2,963) | (2,226) | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (73) | (42) | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [2],[3] | 2,581 | 2,089 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (7) | (5) | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Derivatives Designated As Hedging Instruments Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (4) | (2) | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | EconomicHedgingInstrumentLiabilites1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (6) | (8) | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Effect of Netting and Allocation of Collateral Interest Rate and FX Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 3 | 5 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [4] | 3,598 | 3,058 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents NDT [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [5] | 86 | 85 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 1,591 | 915 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 1,921 | 2,058 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Corporate Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 1,593 | 1,614 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | US Treasury and Government [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 99 | 52 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Foreign Government Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 50 | 82 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | State and municipal debt [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 149 | 263 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Other Fixed Income [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [6] | 30 | 47 |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Middle market lending [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Private Equity Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Real Estate Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Pledged Assets For Zion Station Decommissioning [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 1 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalent Zion [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Funds Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 1 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | MiddleMarketLending Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 85 | 83 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 15 | 12 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 70 | 71 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 472 | 640 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 2,760 | 2,378 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 69 | 31 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | [2],[3] | (2,357) | (1,769) |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 10 | 11 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Designated as Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 6 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Economic hedge Interest and Currency [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 13 | 10 | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | EffectsofNettingandAllocationofCollateral1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | (3) | (5) | |
Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Other Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | |||
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis [Abstract] | |||
Derivative, Fair Value, Amount Offset Against Collateral, Net | 76 | 81 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [1] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 1,438 | 1,409 | |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | (489) | (394) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 949 | 1,015 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (489) | (394) | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (1,276) | (1,101) | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (21) | (9) | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [2],[3] | 808 | 716 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Derivatives Designated As Hedging Instruments Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | EconomicHedgingInstrumentLiabilites1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Effect of Netting and Allocation of Collateral Interest Rate and FX Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [4] | 543 | 648 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents NDT [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [5] | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 230 | 251 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Corporate Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 230 | 251 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | US Treasury and Government [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Foreign Government Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | State and municipal debt [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Other Fixed Income [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [6] | 0 | 0 |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Middle market lending [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 313 | 397 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Private Equity Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Real Estate Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Pledged Assets For Zion Station Decommissioning [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 12 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalent Zion [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Funds Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | MiddleMarketLending Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 12 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 38 | 22 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 38 | 22 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 815 | 690 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 1,470 | 1,290 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 77 | 35 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | [2],[3] | (732) | (635) |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Designated as Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Economic hedge Interest and Currency [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | EffectsofNettingandAllocationofCollateral1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Other Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 42 | 37 | |
Exelon Generation Co L L C [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Current | (449) | (211) | |
Derivative Liability, Noncurrent | (252) | (174) | |
Derivative liabilities, fair value | [7] | 618 | 349 |
Exelon Generation Co L L C [Member] | Cash and Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 283 | 259 | |
Exelon Generation Co L L C [Member] | Restricted cash [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 39 | 127 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [1] | 581 | 168 |
FinancialAssetsFairValueDisclosure1 | 14,764 | 15,035 | |
Deferred Compensation Liability, Current and Noncurrent | (35) | (38) | |
Financial Liabilities Fair Value Disclosure | (736) | (423) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 14,028 | 14,612 | |
Alternative Investment, Fair Value Disclosure | 3,433 | 3,534 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (698) | (381) | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (4,632) | (3,783) | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (94) | (53) | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [2],[3] | 4,028 | 3,455 |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (3) | (4) | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Derivatives Designated As Hedging Instruments Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | (2) | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | EconomicHedgingInstrumentLiabilites1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (6) | (9) | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Effect of Netting and Allocation of Collateral Interest Rate and FX Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 3 | 7 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [4] | 12,825 | 13,431 |
Alternative Investment, Fair Value Disclosure | [4] | 3,433 | 3,510 |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents NDT [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [5] | 338 | 220 |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Equity Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 5,890 | 7,254 | |
Alternative Investment, Fair Value Disclosure | 1,381 | 2,176 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 5,078 | 4,736 | |
Alternative Investment, Fair Value Disclosure | 846 | 510 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Corporate Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 1,823 | 1,865 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | US Treasury and Government [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 2,180 | 1,969 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Foreign Government Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 50 | 82 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | State and municipal debt [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 149 | 263 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Other Fixed Income [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [6] | 876 | 557 |
Alternative Investment, Fair Value Disclosure | [6] | 846 | 510 |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Middle market lending [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 680 | 528 | |
Alternative Investment, Fair Value Disclosure | 367 | 131 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Private Equity Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 329 | 222 | |
Alternative Investment, Fair Value Disclosure | 329 | 222 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Real Estate Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 510 | 471 | |
Alternative Investment, Fair Value Disclosure | 510 | 471 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Pledged Assets For Zion Station Decommissioning [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 9 | 39 | |
Alternative Investment, Fair Value Disclosure | 0 | 24 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalent Zion [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 9 | 2 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Equity Funds Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 1 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | MiddleMarketLending Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 36 | |
Alternative Investment, Fair Value Disclosure | 0 | 24 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 51 | 50 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 5 | 5 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 24 | 23 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 22 | 22 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 1,246 | 1,304 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 4,771 | 4,225 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 146 | 68 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | [2],[3] | (3,671) | (2,989) |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 10 | 6 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Designated as Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 3 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Economic hedge Interest and Currency [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 13 | 10 | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | EffectsofNettingandAllocationofCollateral1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | (3) | (7) | |
Exelon Generation Co L L C [Member] | Fair Value, Measurements, Recurring [Member] | Other Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 42 | 37 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [1] | 581 | 168 |
FinancialAssetsFairValueDisclosure1 | 5,829 | 6,385 | |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | (3) | (63) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 5,826 | 6,322 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (3) | (64) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (642) | (712) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | (2) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [2],[3] | 639 | 650 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 1 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Derivatives Designated As Hedging Instruments Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | EconomicHedgingInstrumentLiabilites1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | (1) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Effect of Netting and Allocation of Collateral Interest Rate and FX Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 2 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [4] | 5,251 | 6,215 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents NDT [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [5] | 252 | 135 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 2,918 | 4,163 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 2,081 | 1,917 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Corporate Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | US Treasury and Government [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 2,081 | 1,917 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Foreign Government Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | State and municipal debt [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Other Fixed Income [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [6] | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Middle market lending [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Private Equity Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Real Estate Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Pledged Assets For Zion Station Decommissioning [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 9 | 2 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalent Zion [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 9 | 2 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Funds Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | MiddleMarketLending Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 29 | 28 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 5 | 5 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 24 | 23 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | (41) | (26) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 541 | 557 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 2 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | [2],[3] | (582) | (585) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | (2) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Designated as Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Economic hedge Interest and Currency [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | EffectsofNettingandAllocationofCollateral1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | (2) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Other Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [1] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 4,102 | 3,729 | |
Deferred Compensation Liability, Current and Noncurrent | (35) | (38) | |
Financial Liabilities Fair Value Disclosure | (493) | (222) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 3,609 | 3,507 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (455) | (179) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (2,963) | (2,226) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (73) | (42) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [2],[3] | 2,581 | 2,089 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (3) | (5) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Derivatives Designated As Hedging Instruments Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | (2) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | EconomicHedgingInstrumentLiabilites1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (6) | (8) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Effect of Netting and Allocation of Collateral Interest Rate and FX Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 3 | 5 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [4] | 3,598 | 3,058 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents NDT [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [5] | 86 | 85 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 1,591 | 915 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 1,921 | 2,058 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Corporate Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 1,593 | 1,614 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | US Treasury and Government [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 99 | 52 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Foreign Government Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 50 | 82 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | State and municipal debt [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 149 | 263 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Other Fixed Income [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [6] | 30 | 47 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Middle market lending [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Private Equity Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Real Estate Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Pledged Assets For Zion Station Decommissioning [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 1 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalent Zion [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Funds Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 1 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | MiddleMarketLending Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 22 | 22 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 22 | 22 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 472 | 640 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 2,760 | 2,378 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 69 | 31 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | [2],[3] | (2,357) | (1,769) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 10 | 8 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Designated as Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 3 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Economic hedge Interest and Currency [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 13 | 10 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | EffectsofNettingandAllocationofCollateral1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | (3) | (5) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Other Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [1] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 1,400 | 1,387 | |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | (240) | (138) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 1,160 | 1,249 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (240) | (138) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (1,027) | (845) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | (21) | (9) | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [2],[3] | 808 | 716 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Derivatives Designated As Hedging Instruments Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | EconomicHedgingInstrumentLiabilites1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Effect of Netting and Allocation of Collateral Interest Rate and FX Liabilities [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [4] | 543 | 648 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents NDT [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [5] | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 230 | 251 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Corporate Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 230 | 251 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | US Treasury and Government [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Foreign Government Debt Securities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | State and municipal debt [Domain] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Other Fixed Income [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | [6] | 0 | 0 |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Middle market lending [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 313 | 397 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Private Equity Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Real Estate Funds [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Pledged Assets For Zion Station Decommissioning [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 12 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalent Zion [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Equity Funds Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | MiddleMarketLending Zion Decom [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 12 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Commodity Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 815 | 690 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 1,470 | 1,290 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Proprietary Trading [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 77 | 35 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | [2],[3] | (732) | (635) |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Interest Rate and Foreign Currency Derivative Assets [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Designated as Hedging Instrument [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Economic hedge Interest and Currency [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | EffectsofNettingandAllocationofCollateral1 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Asset | 0 | 0 | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Other Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 42 | 37 | |
Commonwealth Edison Co [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Current | (26) | (21) | |
Derivative Liability, Noncurrent | (223) | (235) | |
Commonwealth Edison Co [Member] | Cash and Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 93 | 45 | |
Commonwealth Edison Co [Member] | Other assets | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 166 | ||
Commonwealth Edison Co [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 209 | 98 |
FinancialAssetsFairValueDisclosure1 | 209 | 98 | |
Derivative Liability | [9] | (249) | (256) |
Deferred Compensation Liability, Current and Noncurrent | (6) | (8) | |
Financial Liabilities Fair Value Disclosure | (255) | (264) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | (46) | (166) | |
Commonwealth Edison Co [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 209 | 98 |
FinancialAssetsFairValueDisclosure1 | 209 | 98 | |
Derivative Liability | [9] | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 209 | 98 | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 0 | 0 | |
Derivative Liability | [9] | 0 | 0 |
Deferred Compensation Liability, Current and Noncurrent | (6) | (8) | |
Financial Liabilities Fair Value Disclosure | (6) | (8) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | (6) | (8) | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Current | (26) | (21) | |
Derivative Liability, Noncurrent | (223) | (235) | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 0 | 0 | |
Derivative Liability | [9] | (249) | (256) |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | (249) | (256) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | (249) | (256) | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
PECO Energy Co [Member] | Cash and Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 24 | 47 | |
PECO Energy Co [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 111 | 228 |
FinancialAssetsFairValueDisclosure1 | 128 | 245 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | (10) | (11) | |
Financial Liabilities Fair Value Disclosure | (10) | (11) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 118 | 234 | |
PECO Energy Co [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 17 | 17 | |
PECO Energy Co [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 7 | 7 | |
PECO Energy Co [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 10 | 10 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 111 | 228 |
FinancialAssetsFairValueDisclosure1 | 118 | 235 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 118 | 235 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 7 | 7 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 7 | 7 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 10 | 10 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | (10) | (11) | |
Financial Liabilities Fair Value Disclosure | (10) | (11) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 0 | (1) | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 10 | 10 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 10 | 10 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 0 | 0 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 0 | 0 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Cash and Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 7 | 17 | |
Baltimore Gas and Electric Company [Member] | Restricted cash [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 2 | 1 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 4 | 0 |
FinancialAssetsFairValueDisclosure1 | 10 | 6 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | (5) | (5) | |
Financial Liabilities Fair Value Disclosure | (5) | (5) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 5 | 1 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 6 | 6 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 6 | 6 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 4 | 0 |
FinancialAssetsFairValueDisclosure1 | 10 | 6 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 10 | 6 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 6 | 6 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 6 | 6 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 0 | 0 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | (5) | (5) | |
Financial Liabilities Fair Value Disclosure | (5) | (5) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | (5) | (5) | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [8] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 0 | 0 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Mutual Fund [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Pepco Holdings LLC [Member] | Cash and Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 39 | 12 | |
Pepco Holdings LLC [Member] | Other assets | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 19 | ||
Pepco Holdings LLC [Member] | Successor [Member] | Other assets | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 23 | ||
Pepco Holdings LLC [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 147 | 83 |
FinancialAssetsFairValueDisclosure1 | 277 | 212 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | (21) | (25) | |
Financial Liabilities Fair Value Disclosure | (21) | (25) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 256 | 187 | |
Pepco Holdings LLC [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [11] | 0 | (1) |
Pepco Holdings LLC [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 1 | |
Pepco Holdings LLC [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 130 | 129 | |
Pepco Holdings LLC [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 42 | 72 | |
Pepco Holdings LLC [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 15 | 12 | |
Pepco Holdings LLC [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 60 | 45 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 147 | 83 |
FinancialAssetsFairValueDisclosure1 | 202 | 155 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 202 | 155 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [11] | 0 | (1) |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 1 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 55 | 72 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 42 | 72 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 37 | 35 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | (21) | (25) | |
Financial Liabilities Fair Value Disclosure | (21) | (25) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 16 | 10 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [11] | 0 | 0 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 37 | 35 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 15 | 12 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 22 | 23 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 38 | 22 | |
Derivative Liability | 0 | 0 | |
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 38 | 22 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | [11] | 0 | 0 |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability | 0 | 0 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 38 | 22 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 38 | 22 | |
Potomac Electric Power Company [Member] | Cash and Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 15 | 4 | |
Potomac Electric Power Company [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 38 | 36 |
FinancialAssetsFairValueDisclosure1 | 143 | 137 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | (3) | (4) | |
Financial Liabilities Fair Value Disclosure | (3) | (4) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 140 | 133 | |
Potomac Electric Power Company [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Potomac Electric Power Company [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Potomac Electric Power Company [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 105 | 101 | |
Potomac Electric Power Company [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 41 | 44 | |
Potomac Electric Power Company [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 5 | 12 | |
Potomac Electric Power Company [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 59 | 45 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 38 | 36 |
FinancialAssetsFairValueDisclosure1 | 79 | 80 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 79 | 80 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 41 | 44 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 41 | 44 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 27 | 35 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | (3) | (4) | |
Financial Liabilities Fair Value Disclosure | (3) | (4) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 24 | 31 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 27 | 35 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 5 | 12 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 22 | 23 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 37 | 22 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 37 | 22 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 37 | 22 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 37 | 22 | |
Delmarva Power & Light Company [Member] | Cash and Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 8 | 2 | |
Delmarva Power & Light Company [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 16 | 0 |
FinancialAssetsFairValueDisclosure1 | 16 | 0 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | (1) | (1) | |
Financial Liabilities Fair Value Disclosure | (1) | (1) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 15 | (1) | |
Delmarva Power & Light Company [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | [11] | (1) | |
Delmarva Power & Light Company [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 1 | ||
Delmarva Power & Light Company [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 16 | 0 |
FinancialAssetsFairValueDisclosure1 | 16 | 0 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 16 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | [11] | (1) | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 1 | ||
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 0 | 0 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | (1) | (1) | |
Financial Liabilities Fair Value Disclosure | (1) | (1) | |
Financial Asset Liabilities Net Fair Value Disclosure1 | (1) | (1) | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | [11] | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 0 | 0 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | [11] | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Delmarva Power & Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Cash and Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 7 | 2 | |
Atlantic City Electric Company [Member] | Other assets | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | 19 | 23 | |
Atlantic City Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 23 | 29 |
FinancialAssetsFairValueDisclosure1 | 23 | 29 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 23 | 29 | |
Atlantic City Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Atlantic City Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Atlantic City Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 23 | 29 |
FinancialAssetsFairValueDisclosure1 | 23 | 29 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 23 | 29 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 0 | 0 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Cash and Cash Equivalents, Fair Value Disclosure | [10] | 0 | 0 |
FinancialAssetsFairValueDisclosure1 | 0 | 0 | |
Derivative Liability | 0 | ||
Deferred Compensation Liability, Current and Noncurrent | 0 | 0 | |
Financial Liabilities Fair Value Disclosure | 0 | 0 | |
Financial Asset Liabilities Net Fair Value Disclosure1 | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Economic Hedging Instrument Liabilites [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilities [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Derivative Liability, Noncurrent | 0 | ||
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Rabbi Trust Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Cash Equivalents [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | Fixed Income Investments [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | 0 | 0 | |
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Recurring [Member] | 6311 Life Insurance [Member] | |||
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract] | |||
Investments, Fair Value Disclosure | $ 0 | $ 0 | |
[1] | Generation excludes cash of $283 million and $259 million at December 31, 2018 and 2017 and restricted cash of $39 million and $127 million at December 31, 2018 and 2017. Exelon excludes cash of $458 million and $389 million at December 31, 2018 and 2017 and restricted cash of $80 million and $145 million at December 31, 2018 and 2017 and includes long-term restricted cash of $185 million and $85 million at December 31, 2018 and 2017, which is reported in Other deferred debits in the Consolidated Balance Sheets. | ||
[2] | Excludes net assets of less than $1 million at December 31, 2018 and 2017. These items consist of receivables related to pending securities sales, interest and dividend receivables, and payables related to pending securities purchases. | ||
[3] | The amount of unrealized gains/(losses) at Generation totaled less than $1 million and $1 million for the years ended December 31, 2018 and 2017, respectively. The amount of unrealized gains/(losses) at Exelon totaled $1 million for the years ended December 31, 2018 and 2017, respectively. | ||
[4] | Excludes net liabilities of $130 million and $82 million at December 31, 2018 and 2017, respectively. These items consist of receivables related to pending securities sales, interest and dividend receivables, repurchase agreement obligations, and payables related to pending securities purchases. The repurchase agreements are generally short-term in nature with durations generally of 30 days or less. | ||
[5] | Includes $50 million and $77 million of cash received from outstanding repurchase agreements at December 31, 2018 and 2017, respectively, and is offset by an obligation to repay upon settlement of the agreement as discussed in (d) below. | ||
[6] | Includes derivative instruments of $44 million and less than $1 million, which have a total notional amount of $1,432 million and $811 million at December 31, 2018 and 2017, respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the fiscal years ended and do not represent the amount of the company's exposure to credit or market loss. | ||
[7] | Amount represents the net fair value of out-of-the-money derivative contracts containing credit-risk related contingent features after considering the mitigating effects of offsetting positions under master netting arrangements and reflects the actual net liability upon which any potential contingent collateral obligations would be based. | ||
[8] | ComEd excludes cash of $93 million and $45 million at December 31, 2018 and 2017 and restricted cash of $28 million at December 31, 2018 and includes long-term restricted cash of $166 million and $62 million at December 31, 2018 and December 31, 2017, which is reported in Other deferred debits in the Consolidated Balance Sheets. PECO excludes cash of $24 million and $47 million at December 31, 2018 and 2017. BGE excludes cash of $7 million and $17 million at December 31, 2018 and 2017 and restricted cash of $2 million and $1 million at December 31, 2018 and December 31, 2017. | ||
[9] | The amount of unrealized gains/(losses) at ComEd, PECO and BGE totaled less than $1 million for the years ended December 31, 2018 and December 31, 2017. | ||
[10] | PHI excludes cash of $39 million and $12 million at December 31, 2018 and 2017 and includes long term restricted cash of $19 million and $23 million at December 31, 2018 and 2017 which is reported in Other deferred debits in the Consolidated Balance Sheets. Pepco excludes cash of $15 million and $4 million at December 31, 2018 and 2017. DPL excludes cash of $8 million and $2 million at December 31, 2018 and 2017. ACE excludes cash of $7 million and $2 million at December 31, 2018 and 2017 and includes long-term restricted cash of $19 million and $23 million at December 31, 2018 and 2017 at December 31, 2018 and 2017 which is reported in Other deferred debits in the Consolidated Balance Sheets. | ||
[11] | The amount of unrealized gains/(losses) at PHI totaled $1 million for the years ended December 31, 2018 and 2017, respectively. The amount of unrealized gains/(losses) at Pepco totaled less than $1 million for the years ended December 31, 2018 and 2017, respectively. |
Fair Value of Financial Asset_5
Fair Value of Financial Assets and Liabilities Fair Value of Financial Assets and Liabilities - Fair Value Reconciliation of Level 3 Assets and Liabilities Measured on a Recurring Basis (Details) - USD ($) $ in Millions | 12 Months Ended | |||||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||||
Fair Value, Inputs, Level 3 [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | $ 949 | $ 1,015 | $ 993 | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | (98) | (81) | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Noncurrent Payables To Affiliates | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Nuclear Decommissioning Payable | 7 | (8) | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Regulatory assets | 6 | 8 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Change In Collateral | (5) | 20 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases | 231 | 248 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales | (24) | (16) | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances | 0 | (1) | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (123) | (110) | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3 | (22) | (6) | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3 | (38) | (61) | ||||
FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisOtherMiscellaneous | 0 | |||||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 163 | 261 | ||||
Fair Value, Inputs, Level 3 [Member] | Consolidation, Eliminations [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 0 | 0 | 0 | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Noncurrent Payables To Affiliates | 1 | (6) | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Nuclear Decommissioning Payable | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Regulatory assets | (1) | 6 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Change In Collateral | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3 | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3 | 0 | 0 | ||||
FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisOtherMiscellaneous | 0 | |||||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 0 | 0 | ||||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 1,160 | 1,249 | 1,231 | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | (102) | (84) | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Noncurrent Payables To Affiliates | (1) | 6 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Nuclear Decommissioning Payable | 7 | (8) | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Regulatory assets | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Change In Collateral | (5) | 20 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases | 231 | 248 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales | (24) | (16) | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (135) | (110) | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3 | (22) | (6) | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3 | (38) | (61) | ||||
FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisOtherMiscellaneous | 0 | |||||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 163 | 258 | ||||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Nuclear Decommissioning Trust Fund Investments [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 543 | 648 | 677 | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 0 | 3 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Noncurrent Payables To Affiliates | (1) | 6 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Nuclear Decommissioning Payable | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Regulatory assets | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Change In Collateral | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases | 36 | 64 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | (140) | (102) | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3 | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3 | 0 | 0 | ||||
FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisOtherMiscellaneous | 0 | |||||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | (5) | 1 | ||||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Pledged Assets For Zion Station Decommissioning [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 0 | 12 | 19 | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Noncurrent Payables To Affiliates | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Nuclear Decommissioning Payable | 7 | (8) | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Regulatory assets | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Change In Collateral | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases | 1 | 1 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales | (20) | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3 | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3 | 0 | 0 | ||||
FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisOtherMiscellaneous | 0 | |||||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 0 | 0 | ||||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 575 | 552 | 493 | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | [1] | (105) | (90) | |||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Noncurrent Payables To Affiliates | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Nuclear Decommissioning Payable | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Regulatory assets | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Change In Collateral | (5) | 20 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases | 190 | 178 | [2] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales | (4) | (16) | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | 5 | [3] | (8) | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3 | (22) | (6) | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3 | (36) | (50) | ||||
FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisOtherMiscellaneous | [4] | 0 | ||||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 165 | 254 | ||||
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value, Measured on Recurring Basis, Gain (Loss) Included in Earnings | (265) | 352 | ||||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Other Investments [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 42 | 37 | 42 | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 3 | 3 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Noncurrent Payables To Affiliates | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Nuclear Decommissioning Payable | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Regulatory assets | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Change In Collateral | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases | 4 | 5 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3 | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3 | (2) | (11) | ||||
FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisOtherMiscellaneous | ||||||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 3 | 3 | ||||
Commonwealth Edison Co [Member] | ||||||
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Abstract] | ||||||
Realized Investment Gains (Losses) | 17 | 20 | ||||
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | ||||||
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Period Increase (Decrease) | (24) | (18) | ||||
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | (249) | (256) | $ (258) | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Noncurrent Payables To Affiliates | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Nuclear Decommissioning Payable | 0 | 0 | [1] | |||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Regulatory assets | [5] | 7 | 2 | |||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Change In Collateral | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Purchases | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Sales | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Issuances | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Transfers Into Level 3 | 0 | 0 | ||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Transfers out of Level 3 | 0 | 0 | ||||
FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisOtherMiscellaneous | 0 | |||||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 0 | 0 | ||||
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | 6311 Life Insurance [Member] | ||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ||||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset Value | 38 | 22 | ||||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Abstract] | ||||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Noncurrent Payables To Affiliates | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Included In Nuclear Decommissioning Payable | 0 | |||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Included In Regulatory assets | 0 | 0 | ||||
Fair Value Measurement With Unobservable Inputs Reconciliation Recurring Basis Asset Liability Gain Loss Change In Collateral | 0 | $ 0 | ||||
FairValueMeasurementWithUnobservableInputsReconciliationRecurringBasisOtherMiscellaneous | $ 0 | |||||
[1] | Includes a reduction for the reclassification of $265 million and $352 million of realized gains due to the settlement of derivative contracts for the years ended December 31, 2018 and 2017, respectively. | |||||
[2] | Includes $(19) million of fair value from contracts acquired as a result of the Everett Marine Terminal acquisition | |||||
[3] | The amounts represented are life insurance contracts at Pepco | |||||
[4] | Transfers into and out of Level 3 generally occur when the contract tenor becomes less and more observable respectively, primarily due to changes in market liquidity or assumptions for certain commodity contracts. | |||||
[5] | Includes $24 million of decreases in fair value and an increase for realized losses due to settlements of $17 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2018. Includes $18 million of decreases in fair value and an increase for realized losses due to settlements of $20 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2017. |
Fair Value of Financial Asset_6
Fair Value of Financial Assets and Liabilities Fair Value of Financial Assets and Liabilities - Fair Value Assets and Liabilities Measure on Recurring Basis Gain Loss Included in Earnings (Details) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | |
Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | |
Operating Revenue [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | $ (7) | $ 28 | |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 144 | 290 | |
Purchased Power And Fuel [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | (93) | (126) | |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 21 | (36) | |
Other, net [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 3 | 6 | |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | (2) | 4 | |
Operating and Maintenance [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 4 | ||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 0 | ||
Exelon Generation Co L L C [Member] | Operating Revenue [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | (7) | 28 | |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 144 | 290 | |
Exelon Generation Co L L C [Member] | Purchased Power And Fuel [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | (93) | (126) | |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 21 | (36) | |
Exelon Generation Co L L C [Member] | Other, net [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 3 | 6 | |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | (2) | 4 | |
Pepco Holdings LLC [Member] | Other, net [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | $ 3 | ||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | $ 3 | ||
Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 98 | 81 | |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 163 | 261 | |
Fair Value, Inputs, Level 3 [Member] | Exelon Generation Co L L C [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings | 102 | 84 | |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | $ 163 | $ 258 |
Fair Value of Financial Asset_7
Fair Value of Financial Assets and Liabilities Fair Value of Financial Assets and Liabilities - Fair Value Inputs Assets Quantitative Information (Details) - USD ($) | 12 Months Ended | ||||
Dec. 31, 2018 | Dec. 31, 2017 | ||||
Fair Value, Inputs, Level 3 [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Cash Collateral Posted | $ 76,000,000 | $ 81,000,000 | |||
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Derivative assets, fair value | [1],[2] | 443,000,000 | 445,000,000 | ||
Derivative liabilities, fair value | $ (249,000,000) | $ (256,000,000) | |||
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Minimum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Forward power price assets | 12 | 3 | |||
Forward gas price assets | 0.78 | 1.27 | |||
Marketability Reserve | 4.00% | 4.00% | |||
Renewable factor | 86.00% | 88.00% | |||
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Maximum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Forward power price assets | 174 | 124 | |||
Forward gas price assets | 12.38 | 12.8 | |||
Marketability Reserve | 8.00% | 8.00% | |||
Renewable factor | 120.00% | 120.00% | |||
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Minimum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Volatility percentage | 10.00% | 11.00% | |||
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Maximum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Volatility percentage | 277.00% | 139.00% | |||
Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Derivative liabilities, fair value | [1],[2] | $ 56,000,000 | $ 26,000,000 | ||
Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Minimum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Forward power price assets | 14 | 14 | |||
Exelon Generation Co L L C [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Cash Collateral Posted | $ 418,000,000 | $ 497,000,000 | |||
Derivative liabilities, fair value | [3] | 618,000,000 | 349,000,000 | ||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Derivative assets, fair value | $ 443,000,000 | [1],[2] | $ 445,000,000 | [4],[5] | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Minimum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Forward power price assets | 12 | 3 | |||
Forward gas price assets | 0.78 | 1.27 | |||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Maximum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Forward power price assets | 174 | 124 | |||
Forward gas price assets | 12.38 | 12.8 | |||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Minimum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Volatility percentage | 10.00% | 11.00% | |||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Maximum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Volatility percentage | 277.00% | 139.00% | |||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Derivative liabilities, fair value | $ 56,000,000 | [1],[2] | $ 26,000,000 | [4],[5] | |
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Minimum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Forward power price assets | 14 | 14 | |||
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Maximum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Forward power price assets | 174 | 94 | |||
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Derivative liabilities, fair value | $ (249,000,000) | $ (256,000,000) | |||
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Minimum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Marketability Reserve | 4.00% | 4.00% | |||
Renewable factor | 86.00% | 88.00% | |||
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Maximum [Member] | |||||
Fair Value Inputs [Abstract] | |||||
Marketability Reserve | 8.00% | 8.00% | |||
Renewable factor | 120.00% | 120.00% | |||
[1] | The fair values do not include cash collateral posted on level three positions of $76 million as of December 31, 2018. | ||||
[2] | The valuation techniques, unobservable inputs and ranges are the same for the asset and liability positions. | ||||
[3] | Amount represents the net fair value of out-of-the-money derivative contracts containing credit-risk related contingent features after considering the mitigating effects of offsetting positions under master netting arrangements and reflects the actual net liability upon which any potential contingent collateral obligations would be based. | ||||
[4] | The fair values do not include cash collateral posted on level three positions $81 million as of December 31, 2017. | ||||
[5] | The valuation techniques, unobservable inputs and ranges are the same for the asset and liability positions |
Fair Value of Financial Asset_8
Fair Value of Financial Assets and Liabilities Fair Value of Financial Assets and Liabilities - Narrative (Details) - USD ($) | Dec. 31, 2018 | Dec. 31, 2017 |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Spent Nuclear Fuel Obligation, Noncurrent | $ 1,171,000,000 | $ 1,147,000,000 |
Forward Power Basis | 3.18 | |
Forward Gas Basis | 0.64 | |
Exelon Generation Co L L C [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Spent Nuclear Fuel Obligation, Noncurrent | 1,171,000,000 | 1,147,000,000 |
Exelon Generation Co L L C [Member] | Fitzpatrick [Member] | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||
Spent Nuclear Fuel Obligation, Noncurrent | $ 119,000,000 | $ 114,000,000 |
Derivative Financial Instrume_3
Derivative Financial Instruments - Narrative (Details) - USD ($) $ in Thousands | 12 Months Ended | ||||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||
Derivative [Line Items] | |||||
Ineffective portion recognized in income | $ 9,000 | $ 15,000 | $ 14,000 | ||
Cash collateral held | (17,000) | ||||
Letters of credit held | 35,000 | ||||
Derivative, Fair Value, Net | 1,000 | 6,000 | |||
InterestRateAndForeignExchangeContract [Member] | |||||
Derivative [Line Items] | |||||
Derivative, Fair Value, Net | 3,000 | 5,000 | |||
Commodity Contract [Member] | |||||
Derivative [Line Items] | |||||
Derivative, Fair Value, Net | 299,000 | 667,000 | |||
Baltimore Gas and Electric Company [Member] | |||||
Derivative [Line Items] | |||||
Credit exposure under off system sales | 3,000 | ||||
Incremental collateral for loss of investment grade credit rating | 69,000 | ||||
Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Letters of credit posted | 367,000 | 293,000 | |||
Cash collateral held | (47,000) | (35,000) | |||
Letters of credit held | 44,000 | 33,000 | |||
Cash collateral posted | 418,000 | 497,000 | |||
Incremental collateral for loss of investment grade credit rating | 2,100,000 | 1,800,000 | |||
Interest Rate Fair Value Hedge Asset at Fair Value | 7,000 | ||||
Derivative, Collateral, Obligation to Return Cash | 2,000 | 4,000 | |||
Exelon Generation Co L L C [Member] | InterestRateAndForeignExchangeContract [Member] | |||||
Derivative [Line Items] | |||||
Derivative, Fair Value, Net | 7,000 | 2,000 | |||
Exelon Generation Co L L C [Member] | InterestRateAndForeignExchangeContract [Member] | Designated as Hedging Instrument [Member] | |||||
Derivative [Line Items] | |||||
Derivative, Fair Value, Net | 1,000 | ||||
Exelon Generation Co L L C [Member] | Commodity Contract [Member] | |||||
Derivative [Line Items] | |||||
Derivative, Fair Value, Net | $ 548,000 | [1] | $ 923,000 | [2] | |
Commonwealth Edison Company [Member] | Energy Related Derivative [Member] | |||||
Derivative [Line Items] | |||||
Credit Derivative, Collateral Held Directly or by Third Parties | 38,000,000 | ||||
Commonwealth Edison Company [Member] | Other Contract [Member] | |||||
Derivative [Line Items] | |||||
Credit Derivative, Collateral Held Directly or by Third Parties | 19,000,000 | ||||
Commonwealth Edison Company [Member] | Renewable Energy Program [Member] | |||||
Derivative [Line Items] | |||||
Credit Derivative, Collateral Held Directly or by Third Parties | 31,000,000 | ||||
Commonwealth Edison Co [Member] | |||||
Derivative [Line Items] | |||||
Term of contract | 20 years | ||||
Incremental collateral for loss of investment grade credit rating | $ 7,000 | ||||
PECO Energy Co [Member] | |||||
Derivative [Line Items] | |||||
Estimated Percent Of Gas Purchases Being Hedged | 20.00% | ||||
Incremental collateral for loss of investment grade credit rating | $ 39,000 | ||||
Delmarva Power & Light Company [Member] | |||||
Derivative [Line Items] | |||||
Incremental collateral for loss of investment grade credit rating | 11,000 | ||||
Delmarva Power & Light Company [Member] | Energy Related Derivative [Member] | |||||
Derivative [Line Items] | |||||
Brokered Natural Gas Margin Revenue | $ 2,750 | ||||
Minimum [Member] | Baltimore Gas and Electric Company [Member] | |||||
Derivative [Line Items] | |||||
Estimated Percent Of Gas Purchases Being Hedged | 10.00% | ||||
Minimum [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Expected generation hedged in next twelve months | 89.00% | ||||
Expected generation hedged in year two | 56.00% | ||||
Expected generation hedged in year three | 32.00% | ||||
Maximum [Member] | Baltimore Gas and Electric Company [Member] | |||||
Derivative [Line Items] | |||||
Estimated Percent Of Gas Purchases Being Hedged | 20.00% | ||||
Maximum [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Expected generation hedged in next twelve months | 92.00% | ||||
Expected generation hedged in year two | 59.00% | ||||
Expected generation hedged in year three | 35.00% | ||||
Atlantic City Electric Company [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Due From Affiliate Current Electric Utility | $ 5,000 | ||||
PECO Energy Co Affiliate [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Due From Affiliate Current Electric Gas Utility | 30,000 | ||||
Baltimore Gas And Electric Company Affiliate [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Due From Affiliate Current Electric Gas Utility | 24,000 | ||||
Potomac Electric Power Company [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Due From Affiliate Current Electric Utility | 28,000 | ||||
Delmarva Power & Light Company [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Due From Affiliate Current Electric Utility | 7,000 | ||||
Commonwealth Edison Co Affiliate [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Due From Affiliate Current Electric Utility | 43,000 | ||||
Derivative, Collateral, Obligation to Return Cash | $ 12,000 | ||||
[1] | Current and noncurrent assets are shown net of collateral of $121 million and $51 million, respectively, and current and noncurrent liabilities are shown net of collateral of $125 million and $60 million, respectively. The total cash collateral posted, net of cash collateral received and offset against mark-to-market assets and liabilities was $357 million at December 31, 2018. | ||||
[2] | Current and noncurrent assets are shown net of collateral of $169 million and $53 million, respectively, and current and noncurrent liabilities are shown net of collateral of $167 million and $77 million, respectively. The total cash collateral posted, net of cash collateral received and offset against mark-to-market assets and liabilities was $466 million at December 31, 2017. |
Derivative Financial Instrume_4
Derivative Financial Instruments - Summary of Interest Rate and Foreign Currency Hedges (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Derivative [Line Items] | |||
Mark-to-market derivative assets (current assets) | $ 804 | $ 976 | |
Mark-to-market derivative assets (noncurrent assets) | 452 | 337 | |
Derivative Liability, Current | (475) | (232) | |
Derivative Liability, Noncurrent | (479) | (409) | |
Total mark-to-market derivative net assets (liabilities) | 1 | 6 | |
Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Mark-to-market derivative assets (current assets) | 804 | 976 | |
Mark-to-market derivative assets (noncurrent assets) | 452 | 334 | |
Derivative Liability, Current | (449) | (211) | |
Derivative Liability, Noncurrent | (252) | (174) | |
InterestRateAndForeignExchangeContract [Member] | |||
Derivative [Line Items] | |||
Mark-to-market derivative assets (current assets) | 3 | 3 | |
Mark-to-market derivative assets (noncurrent assets) | 7 | 6 | |
Total mark-to-market derivative assets | 10 | 9 | |
Derivative Liability, Current | (2) | (2) | |
Derivative Liability, Noncurrent | (5) | (2) | |
Total mark-to-market derivative liabilities | 7 | 4 | |
Total mark-to-market derivative net assets (liabilities) | 3 | 5 | |
InterestRateAndForeignExchangeContract [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Mark-to-market derivative assets (current assets) | 3 | 3 | |
Mark-to-market derivative assets (noncurrent assets) | 7 | 3 | |
Total mark-to-market derivative assets | 10 | 6 | |
Derivative Liability, Current | (2) | (2) | |
Derivative Liability, Noncurrent | (1) | (2) | |
Total mark-to-market derivative liabilities | 3 | 4 | |
Total mark-to-market derivative net assets (liabilities) | 7 | 2 | |
Designated as Hedging Instrument [Member] | InterestRateAndForeignExchangeContract [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Mark-to-market derivative assets (current assets) | 0 | ||
Mark-to-market derivative assets (noncurrent assets) | 3 | ||
Total mark-to-market derivative assets | 3 | ||
Derivative Liability, Current | (2) | ||
Derivative Liability, Noncurrent | 0 | ||
Total mark-to-market derivative liabilities | 2 | ||
Total mark-to-market derivative net assets (liabilities) | 1 | ||
Not Designated as Hedging Instrument, Economic Hedge [Member] | InterestRateAndForeignExchangeContract [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Mark-to-market derivative assets (current assets) | 5 | 10 | |
Mark-to-market derivative assets (noncurrent assets) | 8 | 0 | |
Total mark-to-market derivative assets | 13 | 10 | |
Derivative Liability, Current | (4) | (7) | |
Derivative Liability, Noncurrent | (2) | (2) | |
Total mark-to-market derivative liabilities | 6 | 9 | |
Total mark-to-market derivative net assets (liabilities) | 7 | 1 | |
Corporate, Non-Segment [Member] | Designated as Hedging Instrument [Member] | InterestRateAndForeignExchangeContract [Member] | |||
Derivative [Line Items] | |||
Mark-to-market derivative assets (current assets) | 0 | ||
Mark-to-market derivative assets (noncurrent assets) | 3 | ||
Total mark-to-market derivative assets | 3 | ||
Derivative Liability, Current | 0 | ||
Derivative Liability, Noncurrent | 0 | ||
Total mark-to-market derivative liabilities | 0 | ||
Total mark-to-market derivative net assets (liabilities) | 3 | ||
Corporate, Non-Segment [Member] | Not Designated as Hedging Instrument, Economic Hedge [Member] | InterestRateAndForeignExchangeContract [Member] | |||
Derivative [Line Items] | |||
Mark-to-market derivative assets (current assets) | 0 | ||
Mark-to-market derivative assets (noncurrent assets) | 0 | ||
Total mark-to-market derivative assets | 0 | ||
Derivative Liability, Current | 0 | ||
Derivative Liability, Noncurrent | (4) | ||
Total mark-to-market derivative liabilities | 4 | ||
Total mark-to-market derivative net assets (liabilities) | (4) | ||
Collateral and Netting | InterestRateAndForeignExchangeContract [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Mark-to-market derivative assets (current assets) | [1] | (2) | (7) |
Mark-to-market derivative assets (noncurrent assets) | [1] | (1) | 0 |
Total mark-to-market derivative assets | [1] | (3) | (7) |
Derivative Liability, Current | [1] | 2 | 7 |
Derivative Liability, Noncurrent | [1] | 1 | 0 |
Total mark-to-market derivative liabilities | [1] | (3) | (7) |
Total mark-to-market derivative net assets (liabilities) | [1] | $ 0 | $ 0 |
[1] | Exelon and Generation net all available amounts allowed under the derivative authoritative guidance on the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases, Exelon and Generation may have other offsetting counterparty exposures subject to a master netting or similar agreement, such as accrued interest, transactions that do not qualify as derivatives, letters of credit and other forms of non-cash collateral, which are not reflected in the table above. |
Derivative Financial Instrume_5
Derivative Financial Instruments - Summary of Gains and Losses on Hedges (Details) - Interest Expense [Member] - Fair Value Hedging [Member] - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Interest Rate Swap [Member] | |||
Derivative [Line Items] | |||
Gain (Loss) on Fair Value Hedges Recognized in Earnings | $ (11) | $ (13) | $ (9) |
Price Risk Derivative [Member] | |||
Derivative [Line Items] | |||
Increase (Decrease) in Fair Value of Hedged Item in Price Risk Fair Value Hedge | $ 20 | $ 28 | $ 23 |
Derivative Financial Instrume_6
Derivative Financial Instruments - Summary of Derivative Fair Value Balances (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |||
Derivative [Line Items] | |||||
Derivative, Collateral, Right to Reclaim Cash | $ 50 | $ 77 | |||
Mark-to-market derivative assets (current assets) | 804 | 976 | |||
Mark-to-market derivative assets (noncurrent assets) | 452 | 337 | |||
Derivative Liability, Current | (475) | (232) | |||
Derivative Liability, Noncurrent | (479) | (409) | |||
Total mark-to-market derivative net assets (liabilities) | 1 | 6 | |||
Margin Deposit Assets | (94) | (117) | |||
Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Mark-to-market derivative assets (current assets) | 804 | 976 | |||
Mark-to-market derivative assets (noncurrent assets) | 452 | 334 | |||
Derivative Liability, Current | (449) | (211) | |||
Derivative Liability, Noncurrent | (252) | (174) | |||
Derivative, Collateral, Obligation to Return Cash | 2 | 4 | |||
Commonwealth Edison Co [Member] | |||||
Derivative [Line Items] | |||||
Derivative Liability, Current | (26) | (21) | |||
Derivative Liability, Noncurrent | (223) | (235) | |||
Commodity Contract [Member] | |||||
Derivative [Line Items] | |||||
Mark-to-market derivative assets (current assets) | 801 | 973 | |||
Mark-to-market derivative assets (noncurrent assets) | 445 | 331 | |||
Total mark-to-market derivative assets | 1,246 | 1,304 | |||
Derivative Liability, Current | (473) | (230) | |||
Derivative Liability, Noncurrent | (474) | (407) | |||
Total mark-to-market derivative liabilities | (947) | (637) | |||
Total mark-to-market derivative net assets (liabilities) | 299 | 667 | |||
Commodity Contract [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Mark-to-market derivative assets (current assets) | 801 | [1] | 973 | [2] | |
Mark-to-market derivative assets (noncurrent assets) | 445 | [1] | 331 | [2] | |
Total mark-to-market derivative assets | 1,246 | [1] | 1,304 | [2] | |
Derivative Liability, Current | (447) | [1] | (209) | [2] | |
Derivative Liability, Noncurrent | (251) | [1] | (172) | [2] | |
Total mark-to-market derivative liabilities | (698) | [1] | (381) | [2] | |
Total mark-to-market derivative net assets (liabilities) | 548 | [1] | 923 | [2] | |
Designated as Hedging Instrument [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Derivative Liability, Collateral, Right to Reclaim Cash, Offset | (357) | (466) | |||
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Mark-to-market derivative assets (current assets) | 3,505 | 3,061 | |||
Mark-to-market derivative assets (noncurrent assets) | 1,266 | 1,164 | |||
Total mark-to-market derivative assets | 4,771 | 4,225 | |||
Derivative Liability, Current | (3,429) | (2,646) | |||
Derivative Liability, Noncurrent | (1,203) | (1,137) | |||
Total mark-to-market derivative liabilities | (4,632) | (3,783) | |||
Total mark-to-market derivative net assets (liabilities) | 139 | 442 | |||
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member] | Commonwealth Edison Co [Member] | |||||
Derivative [Line Items] | |||||
Mark-to-market derivative assets (current assets) | [3] | 0 | 0 | ||
Mark-to-market derivative assets (noncurrent assets) | [3] | 0 | 0 | ||
Total mark-to-market derivative assets | [3] | 0 | 0 | ||
Derivative Liability, Current | [3] | (26) | (21) | ||
Derivative Liability, Noncurrent | [3] | (223) | (235) | ||
Total mark-to-market derivative liabilities | [3] | (249) | (256) | ||
Total mark-to-market derivative net assets (liabilities) | [3] | (249) | (256) | ||
Not Designated as Hedging Instrument, Trading [Member] | Commodity Contract [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Mark-to-market derivative assets (current assets) | 105 | 56 | |||
Mark-to-market derivative assets (noncurrent assets) | 41 | 12 | |||
Total mark-to-market derivative assets | 146 | 68 | |||
Derivative Liability, Current | (74) | (43) | |||
Derivative Liability, Noncurrent | (20) | (10) | |||
Total mark-to-market derivative liabilities | (94) | (53) | |||
Total mark-to-market derivative net assets (liabilities) | 52 | 15 | |||
Other Current Assets [Member] | Designated as Hedging Instrument [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Derivative, Collateral, Right to Reclaim Cash | 121 | 169 | |||
Margin Deposit Assets | (94) | (117) | |||
Other Noncurrent Assets [Member] | Designated as Hedging Instrument [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Derivative, Collateral, Right to Reclaim Cash | 51 | 53 | |||
Other Current Liabilities [Member] | Designated as Hedging Instrument [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Derivative, Collateral, Right to Reclaim Cash | 125 | 167 | |||
Other Noncurrent Liabilities [Member] | Designated as Hedging Instrument [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Derivative, Collateral, Right to Reclaim Cash | 60 | 77 | |||
Collateral and Netting | Commodity Contract [Member] | Exelon Generation Co L L C [Member] | |||||
Derivative [Line Items] | |||||
Mark-to-market derivative assets (current assets) | [4] | (2,809) | [5] | (2,144) | [6] |
Mark-to-market derivative assets (noncurrent assets) | [4] | (862) | [5] | (845) | [6] |
Total mark-to-market derivative assets | [4] | (3,671) | [5] | (2,989) | [6] |
Derivative Liability, Current | [4] | 3,056 | [5] | 2,480 | [6] |
Derivative Liability, Noncurrent | [4] | 972 | [5] | 975 | [6] |
Total mark-to-market derivative liabilities | [4] | 4,028 | [5] | 3,455 | [6] |
Total mark-to-market derivative net assets (liabilities) | [4] | $ 357 | [5] | $ 466 | [6] |
[1] | Current and noncurrent assets are shown net of collateral of $121 million and $51 million, respectively, and current and noncurrent liabilities are shown net of collateral of $125 million and $60 million, respectively. The total cash collateral posted, net of cash collateral received and offset against mark-to-market assets and liabilities was $357 million at December 31, 2018. | ||||
[2] | Current and noncurrent assets are shown net of collateral of $169 million and $53 million, respectively, and current and noncurrent liabilities are shown net of collateral of $167 million and $77 million, respectively. The total cash collateral posted, net of cash collateral received and offset against mark-to-market assets and liabilities was $466 million at December 31, 2017. | ||||
[3] | Includes current and noncurrent liabilities relating to floating-to-fixed energy swap contracts with unaffiliated suppliers. | ||||
[4] | Exelon and Generation net all available amounts allowed under the derivative authoritative guidance on the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases, Exelon and Generation may have other offsetting exposures, subject to a master netting or similar agreement, such as trade receivables and payables, transactions that do not qualify as derivatives, letters of credit and other forms of non-cash collateral. These are not reflected in the table above. | ||||
[5] | Of the collateral posted/(received), $(94) million represents variation margin on the exchanges. | ||||
[6] | Of the collateral posted/(received), $(117) million represents variation margin on the exchanges |
Derivative Financial Instrume_7
Derivative Financial Instruments - Summary of AOCI related to Cash Flow Hedges (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | ||||
Dec. 31, 2018 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||
Derivative [Line Items] | ||||||
Beginning Balance | $ (3,026) | |||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | [1] | (182) | $ (144) | |||
Ending Balance | $ (2,995) | (2,995) | (3,026) | |||
Income Tax Expense (Benefit) | (26) | (120) | 126 | $ (753) | ||
Exelon Generation Co L L C [Member] | ||||||
Derivative [Line Items] | ||||||
Beginning Balance | (37) | |||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | [1] | (1) | (4) | |||
Ending Balance | (38) | (38) | (37) | |||
Income Tax Expense (Benefit) | 108 | 1,376 | (282) | |||
Cash Flow Hedging [Member] | ||||||
Derivative [Line Items] | ||||||
Beginning Balance | (14) | (17) | ||||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | 11 | (1) | ||||
Ending Balance | (2) | (2) | (14) | (17) | ||
Cash Flow Hedging [Member] | Interest Expense [Member] | ||||||
Derivative [Line Items] | ||||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 1 | 4 | [2] | |||
Cash Flow Hedging [Member] | Exelon Generation Co L L C [Member] | ||||||
Derivative [Line Items] | ||||||
Beginning Balance | (16) | (19) | ||||
Derivative Instruments, Gain (Loss) Reclassified from Accumulated OCI into Income, Effective Portion, Net | 11 | (1) | ||||
Ending Balance | $ (4) | (4) | (16) | $ (19) | ||
Cash Flow Hedging [Member] | Exelon Generation Co L L C [Member] | Interest Expense [Member] | ||||||
Derivative [Line Items] | ||||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | $ 1 | 4 | [2] | |||
Reclassification out of Accumulated Other Comprehensive Income [Member] | Cash Flow Hedging [Member] | ||||||
Derivative [Line Items] | ||||||
Income Tax Expense (Benefit) | $ 1 | |||||
[1] | Amounts in parenthesis represent a decrease in net income. | |||||
[2] | Amount is net of related income tax expense of $1 million for the year ended December 31, 2017. |
Derivative Financial Instrume_8
Derivative Financial Instruments - Summary of Economic Hedges (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | $ (294) | $ (151) | $ (24) |
Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | (307) | (167) | (40) |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Foreign Exchange Contract [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | (6) | (9) | (10) |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Foreign Exchange Contract [Member] | Operating Revenue [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | 7 | (6) | (10) |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Foreign Exchange Contract [Member] | Purchased Power And Fuel [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | (9) | 0 | 0 |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Foreign Exchange Contract [Member] | Interest Expense [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | (4) | (3) | 0 |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | (317) | (169) | (31) |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member] | Operating Revenue [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | (270) | (126) | (490) |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member] | Purchased Power And Fuel [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | (47) | (43) | 459 |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Exelon Generation Co L L C [Member] | Foreign Exchange Contract [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | (9) | (9) | (10) |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Exelon Generation Co L L C [Member] | Foreign Exchange Contract [Member] | Operating Revenue [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | 7 | (6) | (10) |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Exelon Generation Co L L C [Member] | Foreign Exchange Contract [Member] | Purchased Power And Fuel [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | (9) | 0 | 0 |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Exelon Generation Co L L C [Member] | Foreign Exchange Contract [Member] | Interest Expense [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | $ (7) | $ (3) | $ 0 |
Derivative Financial Instrume_9
Derivative Financial Instruments - Summary of Proprietary Trading Activities (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | $ (294) | $ (151) | $ (24) |
Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | (307) | (167) | (40) |
Not Designated as Hedging Instrument, Trading [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member] | Operating Revenue [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | 17 | 6 | 2 |
Not Designated as Hedging Instrument, Trading [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member] | Operating Revenue [Member] | |||
Derivative [Line Items] | |||
Unrealized Gain (Loss) on Derivatives | $ 0 | $ (1) | $ (1) |
Derivative Financial Instrum_10
Derivative Financial Instruments - Summary of Credit Risk Exposure (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Derivative [Line Items] | |||
Cash collateral held | $ 17 | ||
Letters of credit held | 35 | ||
Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Cash collateral held | 47 | $ 35 | |
Letters of credit held | 44 | $ 33 | |
Total Exposure Before Credit Collateral [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Investment grade | 795 | ||
Non-investment grade | 133 | ||
Internally rated — investment grade | 181 | ||
Internally rated — non-investment grade | 92 | ||
Total | 1,201 | ||
Credit Collateral [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Investment grade | 0 | ||
Non-investment grade | 45 | ||
Internally rated — investment grade | 1 | ||
Internally rated — non-investment grade | 6 | ||
Total | [1] | 52 | |
Net Exposure [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Investment grade | 795 | ||
Non-investment grade | 88 | ||
Internally rated — investment grade | 180 | ||
Internally rated — non-investment grade | 86 | ||
Total | 1,149 | ||
Number Of Counterparties Greater Than Ten Percent Of Net Exposure [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Investment grade | 1 | ||
Non-investment grade | 0 | ||
Internally rated — investment grade | 0 | ||
Internally rated — non-investment grade | 0 | ||
Total | 1 | ||
Net Exposure Of Counterparties Greater Than Ten Percent Of Net Exposure [Member] | Exelon Generation Co L L C [Member] | |||
Derivative [Line Items] | |||
Investment grade | 153 | ||
Non-investment grade | 0 | ||
Internally rated — investment grade | 0 | ||
Internally rated — non-investment grade | 0 | ||
Total | $ 153 | ||
[1] | As of December 31, 2018, credit collateral held from counterparties where Generation had credit exposure included $17 million of cash and $35 million of letters of credit. The credit collateral does not include non-liquid collateral. |
Derivative Financial Instrum_11
Derivative Financial Instruments - Net Credit Exposure by Type of Counterparty (Details) - Exelon Generation Co L L C [Member] - Net Exposure [Member] $ in Millions | Dec. 31, 2018USD ($) |
Derivative [Line Items] | |
Financial institutions | $ 12 |
Investor-owned utilities, marketers, power producers | 737 |
Energy cooperatives and municipalities | 324 |
Other | 76 |
Total | $ 1,149 |
Derivative Financial Instrum_12
Derivative Financial Instruments - Summary of Credit Risk Related Contingent Features (Details) - Exelon Generation Co L L C [Member] - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Derivative [Line Items] | |||
Derivative Asset, Fair Value, Gross Liability | [1] | $ (1,723) | $ (926) |
Offsetting Fair Value of In-the-Money Contracts Under Master Netting Arrangements | [2] | 1,105 | 577 |
Derivative liabilities, fair value | [3] | $ (618) | $ (349) |
[1] | Amount represents the gross fair value of out-of-the-money derivative contracts containing credit-risk-related contingent features ignoring the effects of master netting agreements. | ||
[2] | Amount represents the offsetting fair value of in-the-money derivative contracts under legally enforceable master netting agreements with the same counterparty, which reduces the amount of any liability for which a Registrant could potentially be required to post collateral. | ||
[3] | Amount represents the net fair value of out-of-the-money derivative contracts containing credit-risk related contingent features after considering the mitigating effects of offsetting positions under master netting arrangements and reflects the actual net liability upon which any potential contingent collateral obligations would be based. |
Derivative Financial Instrum_13
Derivative Financial Instruments - Schedule of Notional Amounts Outstanding (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Derivative [Line Items] | |||
Derivative, Notional Amount | $ 5,991 | $ 3,606 | |
Not Designated as Hedging Instrument, Economic Hedge [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 1,688 | 95 | |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Foreign Exchange Contract [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 268 | 94 | |
Not Designated as Hedging Instrument, Economic Hedge [Member] | Interest Rate Swap [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 1,420 | 1 | [1] |
Exelon Generation Co L L C [Member] | Not Designated as Hedging Instrument, Economic Hedge [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 888 | 95 | |
Exelon Generation Co L L C [Member] | Not Designated as Hedging Instrument, Economic Hedge [Member] | Foreign Exchange Contract [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 268 | 94 | |
Exelon Generation Co L L C [Member] | Not Designated as Hedging Instrument, Economic Hedge [Member] | Interest Rate Swap [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 620 | 1 | |
Exelon Generation Co L L C [Member] | Cash Flow Hedging [Member] | Interest Rate Swap [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 0 | 636 | |
Corporate, Non-Segment [Member] | Not Designated as Hedging Instrument, Economic Hedge [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 800 | 0 | |
Corporate, Non-Segment [Member] | Not Designated as Hedging Instrument, Economic Hedge [Member] | Foreign Exchange Contract [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 0 | 0 | |
Corporate, Non-Segment [Member] | Not Designated as Hedging Instrument, Economic Hedge [Member] | Interest Rate Swap [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | 800 | 0 | |
Corporate, Non-Segment [Member] | Fair Value Hedging [Member] | Interest Rate Swap [Member] | |||
Derivative [Line Items] | |||
Derivative, Notional Amount | $ 0 | $ 800 | |
[1] | On July 1, 2018, Exelon and Generation de-designated its fair value and cash flow hedges. The table excludes amounts of $800 million of fixed-to-floating hedges that were previously designated as fair value hedges by Exelon and $636 million of floating-to-fixed hedges that were previously designated as cash flow hedges by Exelon and Generation as of December 31, 2017. |
Debt and Credit Agreements - Co
Debt and Credit Agreements - Commercial Paper Borrowings Outstanding (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 30, 2018 | Jun. 30, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Mar. 31, 2016 | ||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | [1] | $ 9,704 | ||||||
Average Interest Rate on Commercial Paper Borrowings | 2.15% | 1.24% | 1.12% | |||||
Letters of Credit Outstanding, Amount | $ 1,696 | |||||||
Credit facility agreements with minority and community banks | 135 | $ 128 | ||||||
Commercial Paper [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | [2],[3],[4] | 9,000 | 9,450 | |||||
Outstanding commercial paper | 89 | 427 | ||||||
Revolving Credit Facility [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | $ 500 | |||||||
Exelon Corporate [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Letters of Credit Outstanding, Amount | 9 | |||||||
Exelon Corporate [Member] | Commercial Paper [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | [2],[3] | 600 | 600 | [4] | ||||
Outstanding commercial paper | $ 0 | $ 0 | ||||||
Average Interest Rate on Commercial Paper Borrowings | 1.93% | 1.16% | ||||||
Exelon Generation Co L L C [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | $ 200 | $ 45 | ||||||
Average Interest Rate on Commercial Paper Borrowings | 1.96% | 1.23% | 1.14% | |||||
Credit facility agreements with minority and community banks | $ 49 | $ 75 | $ 49 | |||||
Exelon Generation Co L L C [Member] | Commercial Paper [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | [2],[3] | 5,300 | 5,300 | [4] | ||||
Outstanding commercial paper | $ 0 | $ 0 | ||||||
Average Interest Rate on Commercial Paper Borrowings | 1.96% | 1.23% | ||||||
Exelon Generation Co L L C [Member] | Revolving Credit Facility [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Letters of Credit Outstanding, Amount | $ 545 | $ 480 | ||||||
Exelon Generation Co L L C [Member] | Secured Debt [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Letters of Credit Outstanding, Amount | 159 | $ 179 | ||||||
Exelon Generation Co L L C [Member] | Letter of Credit [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Letters of Credit Outstanding, Amount | $ 5 | |||||||
Commonwealth Edison Co [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Average Interest Rate on Commercial Paper Borrowings | 2.14% | 1.24% | ||||||
Letters of Credit Outstanding, Amount | $ 2 | |||||||
Credit facility agreements with minority and community banks | 33 | $ 34 | ||||||
Commonwealth Edison Co [Member] | Commercial Paper [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | [2],[3] | 1,000 | 1,000 | [4] | ||||
Outstanding commercial paper | $ 0 | $ 0 | ||||||
Average Interest Rate on Commercial Paper Borrowings | 2.14% | 1.24% | ||||||
PECO Energy Co [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Average Interest Rate on Commercial Paper Borrowings | 2.24% | 1.13% | ||||||
Letters of Credit Outstanding, Amount | $ 0 | |||||||
Credit facility agreements with minority and community banks | 34 | $ 34 | ||||||
PECO Energy Co [Member] | Commercial Paper [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | [2],[3] | 600 | 600 | [4] | ||||
Outstanding commercial paper | $ 0 | $ 0 | ||||||
Average Interest Rate on Commercial Paper Borrowings | 2.24% | 1.13% | ||||||
Baltimore Gas and Electric Company [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Average Interest Rate on Commercial Paper Borrowings | 2.18% | 1.28% | 0.95% | |||||
Letters of Credit Outstanding, Amount | $ 1 | |||||||
Credit facility agreements with minority and community banks | 5 | $ 5 | ||||||
Baltimore Gas and Electric Company [Member] | Commercial Paper [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | [2],[3] | 600 | 600 | [4] | ||||
Outstanding commercial paper | $ 35 | $ 77 | ||||||
Average Interest Rate on Commercial Paper Borrowings | 2.18% | 1.28% | ||||||
Baltimore Gas and Electric Company [Member] | Letter of Credit [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Letters of Credit Outstanding, Amount | $ 2 | |||||||
Pepco Holdings LLC [Member] | Revolving Credit Facility [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | $ 1,500 | |||||||
Potomac Electric Power Company [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Average Interest Rate on Commercial Paper Borrowings | 2.24% | 1.06% | 0.90% | |||||
Letters of Credit Outstanding, Amount | $ 8 | |||||||
Credit facility agreements with minority and community banks | 5 | $ 2 | ||||||
Potomac Electric Power Company [Member] | Commercial Paper [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | [2],[3] | 300 | 500 | [4] | ||||
Outstanding commercial paper | $ 40 | $ 26 | ||||||
Average Interest Rate on Commercial Paper Borrowings | 2.24% | 1.06% | ||||||
Delmarva Power & Light Company [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Average Interest Rate on Commercial Paper Borrowings | 2.07% | 1.48% | ||||||
Letters of Credit Outstanding, Amount | $ 1 | |||||||
Credit facility agreements with minority and community banks | 5 | $ 2 | ||||||
Delmarva Power & Light Company [Member] | Commercial Paper [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | [2],[3] | 300 | 500 | [4] | ||||
Outstanding commercial paper | $ 0 | $ 216 | ||||||
Average Interest Rate on Commercial Paper Borrowings | 2.07% | 1.48% | ||||||
Atlantic City Electric Company [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Average Interest Rate on Commercial Paper Borrowings | 2.21% | 1.43% | ||||||
Letters of Credit Outstanding, Amount | $ 0 | |||||||
Credit facility agreements with minority and community banks | 5 | $ 2 | ||||||
Atlantic City Electric Company [Member] | Commercial Paper [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | [2],[3] | 300 | 350 | [4] | ||||
Outstanding commercial paper | $ 14 | $ 108 | ||||||
Average Interest Rate on Commercial Paper Borrowings | 2.21% | 1.43% | ||||||
Maximum [Member] | Pepco Holdings LLC [Member] | Revolving Credit Facility [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | $ 900 | |||||||
Maximum [Member] | Delmarva Power & Light Company [Member] | Revolving Credit Facility [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | 0 | |||||||
Maximum [Member] | Atlantic City Electric Company [Member] | Revolving Credit Facility [Member] | ||||||||
Short-term Debt [Line Items] | ||||||||
Line of credit facility, maximum borrowing capacity | $ 0 | |||||||
[1] | Excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million, $33 million, $34 million, $5 million, $5 million, $5 million and $5 million, respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. As of December 31, 2018, letters of credit issued under these facilities totaled $5 million and $2 million for Generation and BGE, respectively. | |||||||
[2] | At December 31, 2018, excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million, $33 million, $34 million, $5 million, $5 million, $5 million and $5 million, respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. At December 31, 2017, excludes $128 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million, $34 million, $34 million, $5 million, $2 million, $2 million, and $2 million, respectively. | |||||||
[3] | Excludes $545 million and $480 million in bilateral credit facilities at December 31, 2018 and 2017, respectively, and $159 million and $179 million in credit facilities for project finance at December 31, 2018 and 2017, respectively. These credit facilities do not back Generation's commercial paper program. | |||||||
[4] | Pepco, DPL and ACE's revolving credit facility is subject to available borrowing capacity. The borrowing capacity may be increased or decreased during the term of the facility, except that (i) the sum of the borrowing capacity must equal the total amount of the facility, and (ii) the aggregate amount of credit used at any given time by each of Pepco, DPL or ACE may not exceed $900 million or the maximum amount of short-term debt the company is permitted to have outstanding by its regulatory authorities. The total number of the borrowing reallocations may not exceed eight per year during the term of the facility. |
Debt and Credit Agreements - Su
Debt and Credit Agreements - Summary of Bank Commitments, Credit Facility Borrowings and Available Capacity (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 30, 2018 | Jun. 30, 2018 | Dec. 31, 2017 | Mar. 31, 2016 | |
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | $ 9,704 | ||||
Facility draws | 0 | |||||
Outstanding letters of credit | 1,696 | |||||
Actual available capacity | 8,008 | |||||
To Support Additional Commercial Paper | 7,687 | |||||
Credit facility agreements with minority and community banks | 135 | $ 128 | ||||
Revolving Credit Facility [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | $ 500 | |||||
Exelon Corporate [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Facility draws | 0 | |||||
Outstanding letters of credit | 9 | |||||
Actual available capacity | 591 | |||||
Exelon Generation Co L L C [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | 200 | $ 45 | ||||
To Support Additional Commercial Paper | 4,097 | |||||
Credit facility agreements with minority and community banks | 49 | $ 75 | 49 | |||
Exelon Generation Co L L C [Member] | Secured Debt [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Outstanding letters of credit | 159 | 179 | ||||
Exelon Generation Co L L C [Member] | Revolving Credit Facility [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Outstanding letters of credit | 545 | 480 | ||||
Exelon Generation Co L L C [Member] | Letter of Credit [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Outstanding letters of credit | 5 | |||||
Exelon Generation Co L L C [Member] | Line of Credit [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | 150 | |||||
Actual available capacity | 192 | |||||
To Support Additional Commercial Paper | 0 | |||||
Credit facility agreements with minority and community banks | 30 | |||||
Commonwealth Edison Co [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Facility draws | 0 | |||||
Outstanding letters of credit | 2 | |||||
Actual available capacity | 998 | |||||
To Support Additional Commercial Paper | 998 | |||||
Credit facility agreements with minority and community banks | 33 | 34 | ||||
PECO Energy Co [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Facility draws | 0 | |||||
Outstanding letters of credit | 0 | |||||
Actual available capacity | 600 | |||||
To Support Additional Commercial Paper | 600 | |||||
Credit facility agreements with minority and community banks | 34 | 34 | ||||
Baltimore Gas and Electric Company [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Facility draws | 0 | |||||
Outstanding letters of credit | 1 | |||||
Actual available capacity | 599 | |||||
To Support Additional Commercial Paper | 564 | |||||
Credit facility agreements with minority and community banks | 5 | 5 | ||||
Baltimore Gas and Electric Company [Member] | Letter of Credit [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Outstanding letters of credit | 2 | |||||
Potomac Electric Power Company [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Facility draws | 0 | |||||
Outstanding letters of credit | 8 | |||||
Actual available capacity | 292 | |||||
To Support Additional Commercial Paper | 252 | |||||
Credit facility agreements with minority and community banks | 5 | 2 | ||||
Pepco Holdings LLC [Member] | Revolving Credit Facility [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | 1,500 | |||||
Delmarva Power & Light Company [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Facility draws | 0 | |||||
Outstanding letters of credit | 1 | |||||
Actual available capacity | 299 | |||||
To Support Additional Commercial Paper | 299 | |||||
Credit facility agreements with minority and community banks | 5 | 2 | ||||
Atlantic City Electric Company [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Facility draws | 0 | |||||
Outstanding letters of credit | 0 | |||||
Actual available capacity | 300 | |||||
To Support Additional Commercial Paper | 286 | |||||
Credit facility agreements with minority and community banks | 5 | $ 2 | ||||
Line of Credit [Member] | Exelon Generation Co L L C [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 545 | ||||
Facility draws | 0 | |||||
Outstanding letters of credit | 353 | |||||
Line of Credit [Member] | Exelon Generation Co L L C [Member] | Secured Debt [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 159 | ||||
Facility draws | 0 | |||||
Outstanding letters of credit | 119 | |||||
Actual available capacity | 40 | |||||
To Support Additional Commercial Paper | 0 | |||||
Revolving Credit Facility [Member] | Exelon Corporate [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 600 | ||||
To Support Additional Commercial Paper | 591 | |||||
Revolving Credit Facility [Member] | Exelon Generation Co L L C [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 5,300 | ||||
Facility draws | 0 | |||||
Outstanding letters of credit | 1,203 | |||||
Actual available capacity | 4,097 | |||||
Revolving Credit Facility [Member] | Commonwealth Edison Co [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 1,000 | ||||
Revolving Credit Facility [Member] | PECO Energy Co [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 600 | ||||
Revolving Credit Facility [Member] | Baltimore Gas and Electric Company [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 600 | ||||
Revolving Credit Facility [Member] | Potomac Electric Power Company [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 300 | ||||
Revolving Credit Facility [Member] | Delmarva Power & Light Company [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 300 | ||||
Revolving Credit Facility [Member] | Atlantic City Electric Company [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 300 | ||||
Maximum [Member] | Pepco Holdings LLC [Member] | Revolving Credit Facility [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | 900 | |||||
Maximum [Member] | Delmarva Power & Light Company [Member] | Revolving Credit Facility [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | 0 | |||||
Maximum [Member] | Atlantic City Electric Company [Member] | Revolving Credit Facility [Member] | ||||||
Short-term Debt [Line Items] | ||||||
Line of credit facility, maximum borrowing capacity | $ 0 | |||||
[1] | Excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million, $33 million, $34 million, $5 million, $5 million, $5 million and $5 million, respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. As of December 31, 2018, letters of credit issued under these facilities totaled $5 million and $2 million for Generation and BGE, respectively. |
Debt and Credit Agreements - _2
Debt and Credit Agreements - Summary of Short-term Borrowing Activities (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Short-term Debt [Line Items] | |||
Average borrowings | $ 531 | $ 823 | $ 1,125 |
Maximum borrowings outstanding | $ 1,237 | $ 2,147 | $ 3,076 |
Short-term Debt, Weighted Average Interest Rate, over Time | 2.21% | 1.32% | 0.88% |
Average interest rates at year end | 2.15% | 1.24% | 1.12% |
Exelon Generation Co L L C [Member] | |||
Short-term Debt [Line Items] | |||
Average borrowings | $ 37 | $ 405 | $ 536 |
Maximum borrowings outstanding | $ 583 | $ 1,455 | $ 1,735 |
Short-term Debt, Weighted Average Interest Rate, over Time | 1.96% | 1.23% | 0.94% |
Average interest rates at year end | 1.96% | 1.23% | 1.14% |
Commonwealth Edison Co [Member] | |||
Short-term Debt [Line Items] | |||
Average borrowings | $ 154 | $ 200 | $ 256 |
Maximum borrowings outstanding | $ 520 | $ 470 | $ 755 |
Short-term Debt, Weighted Average Interest Rate, over Time | 2.14% | 1.24% | 0.77% |
Average interest rates at year end | 2.14% | 1.24% | |
PECO Energy Co [Member] | |||
Short-term Debt [Line Items] | |||
Average borrowings | $ 68 | $ 2 | $ 0 |
Maximum borrowings outstanding | $ 350 | $ 60 | 0 |
Short-term Debt, Weighted Average Interest Rate, over Time | 2.24% | 1.13% | |
Average interest rates at year end | 2.24% | 1.13% | |
Baltimore Gas and Electric Company [Member] | |||
Short-term Debt [Line Items] | |||
Average borrowings | $ 65 | $ 54 | 143 |
Maximum borrowings outstanding | $ 239 | $ 165 | $ 369 |
Short-term Debt, Weighted Average Interest Rate, over Time | 2.18% | 1.28% | 0.77% |
Average interest rates at year end | 2.18% | 1.28% | 0.95% |
Pepco Holdings LLC [Member] | |||
Short-term Debt [Line Items] | |||
Short-term Bank Loans and Notes Payable | $ 500 | ||
Average borrowings | $ 153 | ||
Maximum borrowings outstanding | $ 559 | ||
Short-term Debt, Weighted Average Interest Rate, over Time | 1.03% | ||
Potomac Electric Power Company [Member] | |||
Short-term Debt [Line Items] | |||
Average borrowings | 22 | $ 51 | $ 4 |
Maximum borrowings outstanding | $ 90 | $ 197 | $ 73 |
Short-term Debt, Weighted Average Interest Rate, over Time | 2.24% | 1.06% | 0.71% |
Average interest rates at year end | 2.24% | 1.06% | 0.90% |
Delmarva Power & Light Company [Member] | |||
Short-term Debt [Line Items] | |||
Average borrowings | $ 87 | $ 40 | $ 33 |
Maximum borrowings outstanding | $ 245 | $ 216 | $ 116 |
Short-term Debt, Weighted Average Interest Rate, over Time | 2.07% | 1.48% | 0.68% |
Average interest rates at year end | 2.07% | 1.48% | |
Atlantic City Electric Company [Member] | |||
Short-term Debt [Line Items] | |||
Short-term Bank Loans and Notes Payable | $ 125 | ||
Average borrowings | 95 | $ 30 | $ 0 |
Maximum borrowings outstanding | $ 210 | $ 133 | $ 5 |
Short-term Debt, Weighted Average Interest Rate, over Time | 2.21% | 1.43% | 0.65% |
Average interest rates at year end | 2.21% | 1.43% |
Debt and Credit Agreements - _3
Debt and Credit Agreements - Summary of Credit Facility Thresholds (Details) | 12 Months Ended |
Dec. 31, 2018 | |
Line of Credit Facility [Line Items] | |
Credit agreement threshold | 2.50 |
Prime Rate [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 27.50% |
London Interbank Offered Rate (LIBOR) [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 127.50% |
Exelon Generation Co L L C [Member] | |
Line of Credit Facility [Line Items] | |
Credit agreement threshold | 3 |
Exelon Generation Co L L C [Member] | Prime Rate [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 27.50% |
Exelon Generation Co L L C [Member] | London Interbank Offered Rate (LIBOR) [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 127.50% |
Commonwealth Edison Co [Member] | |
Line of Credit Facility [Line Items] | |
Credit agreement threshold | 2 |
Commonwealth Edison Co [Member] | Prime Rate [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 7.50% |
Commonwealth Edison Co [Member] | London Interbank Offered Rate (LIBOR) [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 107.50% |
PECO Energy Co [Member] | |
Line of Credit Facility [Line Items] | |
Credit agreement threshold | 2 |
PECO Energy Co [Member] | Prime Rate [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 0.00% |
PECO Energy Co [Member] | London Interbank Offered Rate (LIBOR) [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 90.00% |
Baltimore Gas and Electric Company [Member] | |
Line of Credit Facility [Line Items] | |
Credit agreement threshold | 2 |
Baltimore Gas and Electric Company [Member] | Prime Rate [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 0.00% |
Baltimore Gas and Electric Company [Member] | London Interbank Offered Rate (LIBOR) [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 100.00% |
Potomac Electric Power Company [Member] | |
Line of Credit Facility [Line Items] | |
Credit agreement threshold | 2 |
Potomac Electric Power Company [Member] | Prime Rate [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 7.50% |
Potomac Electric Power Company [Member] | London Interbank Offered Rate (LIBOR) [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 107.50% |
Delmarva Power & Light Company [Member] | |
Line of Credit Facility [Line Items] | |
Credit agreement threshold | 2 |
Delmarva Power & Light Company [Member] | Prime Rate [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 7.50% |
Delmarva Power & Light Company [Member] | London Interbank Offered Rate (LIBOR) [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 107.50% |
Atlantic City Electric Company [Member] | |
Line of Credit Facility [Line Items] | |
Credit agreement threshold | 2 |
Atlantic City Electric Company [Member] | Prime Rate [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 7.50% |
Atlantic City Electric Company [Member] | London Interbank Offered Rate (LIBOR) [Member] | |
Line of Credit Facility [Line Items] | |
Line of Credit Facility, Interest Rate at Period End | 107.50% |
Debt and Credit Agreements - _4
Debt and Credit Agreements - Summary of Interest Coverage Ratios (Details) | 12 Months Ended |
Dec. 31, 2018 | |
Debt Instrument [Line Items] | |
Debt Instrument, Covenant Compliance | 7.34 |
Exelon Generation Co L L C [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Covenant Compliance | 10.99 |
Commonwealth Edison Co [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Covenant Compliance | 7.34 |
PECO Energy Co [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Covenant Compliance | 8.14 |
Baltimore Gas and Electric Company [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Covenant Compliance | 9.77 |
Potomac Electric Power Company [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Covenant Compliance | 5.98 |
Delmarva Power & Light Company [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Covenant Compliance | 7.03 |
Atlantic City Electric Company [Member] | |
Debt Instrument [Line Items] | |
Debt Instrument, Covenant Compliance | 5.06 |
Debt and Credit Agreements - _5
Debt and Credit Agreements - Summary of Outstanding Long-term Debt (Details) - USD ($) $ in Millions | 1 Months Ended | 9 Months Ended | 12 Months Ended | |||||
Feb. 08, 2019 | Sep. 30, 2018 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Jun. 30, 2014 | |||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | $ 1,349 | |||||||
Long-term Debt, Gross | 34,911 | $ 33,657 | ||||||
Unamortized debt discount and premium, net | (66) | (57) | ||||||
Unamortized Debt Issuance Expense | (216) | (201) | ||||||
Fair value adjustment | 795 | 865 | ||||||
Long-term debt due within one year | (1,349) | [1] | (2,088) | |||||
Long-term debt | 34,075 | 32,176 | ||||||
Long-term debt to financing trusts | 390 | 389 | ||||||
2,020 | 3,528 | |||||||
2,021 | 1,511 | |||||||
Repayments of Long-term Debt | 1,786 | 2,490 | $ 1,936 | |||||
ComEd Financing III Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | 206 | 205 | ||||||
PECO Trust III Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | 81 | 81 | ||||||
PECO Trust IV Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | 103 | 103 | ||||||
Secured Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [2] | $ 16,496 | 15,197 | |||||
Secured Debt [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [2] | 1.70% | ||||||
Secured Debt [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [2] | 7.90% | ||||||
Senior Notes [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 11,285 | 11,285 | ||||||
Senior Notes [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.45% | |||||||
Senior Notes [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 7.60% | |||||||
Unsecured Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 2,900 | 2,600 | ||||||
Unsecured Debt [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.40% | |||||||
Unsecured Debt [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 6.35% | |||||||
Pollution Control Notes [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 435 | 435 | ||||||
Pollution Control Notes [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.50% | |||||||
Pollution Control Notes [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.70% | |||||||
Notes Payable to Banks [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 39 | 82 | ||||||
Notes Payable to Banks [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.15% | |||||||
Notes Payable, Other Payables [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [3],[4] | $ 188 | 405 | |||||
Unamortized Debt Issuance Expense | $ 0 | $ (1) | ||||||
Notes Payable, Other Payables [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [3],[4] | 2.85% | ||||||
Notes Payable, Other Payables [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [3],[4] | 8.88% | ||||||
Junior Subordinated Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.497% | 2.50% | ||||||
Long-term Debt, Gross | $ 1,150 | $ 1,150 | ||||||
Junior Subordinated Debt [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.50% | |||||||
Software License Arrangement [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 73 | 79 | ||||||
Software License Arrangement [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.95% | |||||||
Tax-exempt Money Market Funds [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 112 | 112 | ||||||
Tax-exempt Money Market Funds [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 1.74% | |||||||
Tax-exempt Money Market Funds [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.40% | |||||||
Medium-term Notes [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 22 | 26 | ||||||
Medium-term Notes [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 7.61% | |||||||
Medium-term Notes [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 7.72% | |||||||
Transition Bonds [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 59 | 90 | ||||||
Transition Bonds [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.55% | |||||||
Loans Payable [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 50 | 0 | ||||||
Loans Payable [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.00% | |||||||
Non Recourse Fixed Rate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 1,253 | 1,331 | ||||||
Non Recourse Fixed Rate [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.29% | |||||||
Non Recourse Fixed Rate [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 6.00% | |||||||
Non Recourse Variable Rate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [5] | $ 849 | 865 | |||||
Non Recourse Variable Rate [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [5] | 5.81% | ||||||
Capital Lease Obligations [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Capital lease obligations, noncurrent | $ 36 | 53 | ||||||
Due in 2019 | 21 | |||||||
Due in 2020 | 5 | |||||||
Due in 2021 | 1 | |||||||
Due in 2022 | 1 | |||||||
Due in 2023 | 0 | |||||||
Thereafter | 8 | |||||||
Long-term Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | 390 | 390 | ||||||
Long-term Debt [Member] | ComEd Financing III Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | [6] | $ 206 | 206 | |||||
Long-term Debt [Member] | ComEd Financing III Affiliate [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [6] | 6.35% | ||||||
Long-term Debt [Member] | PECO Trust III Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | [6] | $ 81 | 81 | |||||
Long-term Debt [Member] | PECO Trust III Affiliate [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [6] | 7.38% | ||||||
Long-term Debt [Member] | PECO Trust III Affiliate [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [6] | 7.50% | ||||||
Long-term Debt [Member] | PECO Trust IV Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | [6] | $ 103 | 103 | |||||
Long-term Debt [Member] | PECO Trust IV Affiliate [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [6] | 5.75% | ||||||
Exelon Generation Co L L C [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | $ 906 | |||||||
Long-term Debt, Gross | 8,759 | 8,955 | ||||||
Unamortized debt discount and premium, net | (6) | (8) | ||||||
Unamortized Debt Issuance Expense | (51) | (60) | ||||||
Fair value adjustment | 91 | 103 | ||||||
Long-term debt due within one year | (906) | (346) | ||||||
Long-term debt | 6,989 | 7,734 | ||||||
Debt and Capital Lease Obligations | 7,887 | 8,644 | ||||||
2,020 | 2,108 | |||||||
2,021 | 1 | |||||||
Repayments of Long-term Debt | 141 | 1,261 | 202 | |||||
Exelon Generation Co L L C [Member] | Senior Notes [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 6,019 | 6,019 | ||||||
Exelon Generation Co L L C [Member] | Senior Notes [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.95% | |||||||
Exelon Generation Co L L C [Member] | Senior Notes [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 7.60% | |||||||
Exelon Generation Co L L C [Member] | Pollution Control Notes [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 435 | 435 | ||||||
Exelon Generation Co L L C [Member] | Pollution Control Notes [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.50% | |||||||
Exelon Generation Co L L C [Member] | Pollution Control Notes [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.70% | |||||||
Exelon Generation Co L L C [Member] | Notes Payable to Banks [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 39 | 82 | ||||||
Exelon Generation Co L L C [Member] | Notes Payable to Banks [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 3.15% | |||||||
Exelon Generation Co L L C [Member] | Notes Payable, Other Payables [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [7],[8] | $ 164 | 223 | |||||
Exelon Generation Co L L C [Member] | Notes Payable, Other Payables [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [7],[8] | 2.85% | ||||||
Exelon Generation Co L L C [Member] | Notes Payable, Other Payables [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [7],[8] | 7.83% | ||||||
Exelon Generation Co L L C [Member] | Non Recourse Fixed Rate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 1,253 | 1,331 | ||||||
Exelon Generation Co L L C [Member] | Non Recourse Fixed Rate [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.29% | |||||||
Exelon Generation Co L L C [Member] | Non Recourse Fixed Rate [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 6.00% | |||||||
Exelon Generation Co L L C [Member] | Non Recourse Variable Rate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [9] | $ 849 | 865 | |||||
Exelon Generation Co L L C [Member] | Non Recourse Variable Rate [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [9] | 5.81% | ||||||
Exelon Generation Co L L C [Member] | Capital Lease Obligations [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Capital lease obligations, noncurrent | $ 14 | 18 | ||||||
Due in 2019 | 7 | |||||||
Due in 2020 | 5 | |||||||
Due in 2021 | 1 | |||||||
Due in 2022 | 1 | |||||||
Due in 2023 | 0 | |||||||
Commonwealth Edison Co [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | 300 | |||||||
Long-term Debt, Gross | 8,187 | 7,676 | ||||||
Unamortized debt discount and premium, net | (23) | (23) | ||||||
Unamortized Debt Issuance Expense | (63) | (52) | ||||||
Long-term debt due within one year | (300) | [10] | (840) | |||||
Long-term debt | 7,801 | 6,761 | ||||||
Long-term debt to financing trusts | 205 | 205 | ||||||
Debt and Capital Lease Obligations | 7,801 | 6,761 | ||||||
2,020 | 500 | |||||||
2,021 | 350 | |||||||
Repayments of Long-term Debt | 840 | 425 | 665 | |||||
Commonwealth Edison Co [Member] | ComEd Financing III Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Unamortized Debt Issuance Expense | (1) | (1) | ||||||
Long-term debt to financing trusts | 205 | 205 | ||||||
Commonwealth Edison Co [Member] | Secured Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [11] | $ 8,179 | 7,529 | |||||
Commonwealth Edison Co [Member] | Secured Debt [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [11] | 2.15% | ||||||
Commonwealth Edison Co [Member] | Secured Debt [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [11] | 6.45% | ||||||
Commonwealth Edison Co [Member] | Notes Payable, Other Payables [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [12] | $ 8 | 147 | |||||
Commonwealth Edison Co [Member] | Notes Payable, Other Payables [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [12] | |||||||
Commonwealth Edison Co [Member] | Notes Payable, Other Payables [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [12] | 7.49% | ||||||
Commonwealth Edison Co [Member] | Capital Lease Obligations [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Capital lease obligations, noncurrent | $ 8 | |||||||
Thereafter | 1 | |||||||
Commonwealth Edison Co [Member] | Long-term Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | 206 | 206 | ||||||
Commonwealth Edison Co [Member] | Long-term Debt [Member] | ComEd Financing III Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | [13] | $ 206 | 206 | |||||
Commonwealth Edison Co [Member] | Long-term Debt [Member] | ComEd Financing III Affiliate [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [13] | 6.35% | ||||||
PECO Energy Co [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | $ 0 | |||||||
Long-term Debt, Gross | 3,125 | 2,925 | ||||||
Unamortized debt discount and premium, net | (18) | (5) | ||||||
Unamortized Debt Issuance Expense | (23) | (17) | ||||||
Long-term debt | 3,084 | 2,403 | ||||||
Long-term debt to financing trusts | [14] | 184 | 184 | |||||
Long-term debt due within one year | 0 | (500) | ||||||
Debt and Capital Lease Obligations | 3,084 | 2,403 | ||||||
2,020 | 0 | |||||||
2,021 | 300 | |||||||
Repayments of Long-term Debt | 500 | 0 | 300 | |||||
PECO Energy Co [Member] | PECO Trust III Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | 81 | 81 | ||||||
PECO Energy Co [Member] | PECO Trust IV Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | 103 | 103 | ||||||
PECO Energy Co [Member] | Secured Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [15] | $ 3,075 | 2,925 | |||||
PECO Energy Co [Member] | Secured Debt [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [15] | 1.70% | ||||||
PECO Energy Co [Member] | Secured Debt [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [15] | 5.95% | ||||||
PECO Energy Co [Member] | Loans Payable [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 50 | 0 | ||||||
PECO Energy Co [Member] | Loans Payable [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.00% | |||||||
PECO Energy Co [Member] | Long-term Debt [Member] | PECO Trust III Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | [14] | $ 81 | 81 | |||||
PECO Energy Co [Member] | Long-term Debt [Member] | PECO Trust III Affiliate [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [14] | 7.38% | ||||||
PECO Energy Co [Member] | Long-term Debt [Member] | PECO Trust III Affiliate [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [14] | 7.50% | ||||||
PECO Energy Co [Member] | Long-term Debt [Member] | PECO Trust IV Affiliate [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term debt to financing trusts | [14] | $ 103 | 103 | |||||
PECO Energy Co [Member] | Long-term Debt [Member] | PECO Trust IV Affiliate [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [14] | 5.75% | ||||||
Baltimore Gas and Electric Company [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | $ 0 | |||||||
Long-term Debt, Gross | 2,900 | 2,600 | ||||||
Unamortized debt discount and premium, net | (6) | (6) | ||||||
Unamortized Debt Issuance Expense | (18) | (17) | ||||||
Long-term debt | 2,876 | 2,577 | ||||||
Long-term debt | 2,876 | 2,577 | ||||||
2,020 | 0 | |||||||
2,021 | 300 | |||||||
Repayments of Long-term Debt | 0 | 41 | 379 | |||||
Baltimore Gas and Electric Company [Member] | Senior Notes [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 2,900 | 2,600 | ||||||
Baltimore Gas and Electric Company [Member] | Senior Notes [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 2.40% | |||||||
Baltimore Gas and Electric Company [Member] | Senior Notes [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 6.35% | |||||||
Pepco Holdings LLC [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | $ 125 | |||||||
Long-term Debt, Gross | 5,636 | 5,189 | ||||||
Unamortized debt discount and premium, net | 4 | 5 | ||||||
Unamortized Debt Issuance Expense | (14) | (6) | ||||||
Fair value adjustment | 633 | 686 | ||||||
Long-term debt | 6,134 | 5,478 | ||||||
Long-term debt due within one year | (125) | (396) | ||||||
Long-term debt | 6,134 | 5,478 | ||||||
2,020 | 20 | |||||||
2,021 | 261 | |||||||
Repayments of Long-term Debt | 299 | 169 | ||||||
Pepco Holdings LLC [Member] | Secured Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [16] | $ 5,242 | 4,743 | |||||
Pepco Holdings LLC [Member] | Secured Debt [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [16] | 1.81% | ||||||
Pepco Holdings LLC [Member] | Secured Debt [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [16] | 7.90% | ||||||
Pepco Holdings LLC [Member] | Unsecured Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 185 | 185 | ||||||
Pepco Holdings LLC [Member] | Unsecured Debt [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 7.45% | |||||||
Pepco Holdings LLC [Member] | Notes Payable, Other Payables [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [17] | $ 16 | 33 | |||||
Pepco Holdings LLC [Member] | Notes Payable, Other Payables [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [17] | 7.28% | ||||||
Pepco Holdings LLC [Member] | Notes Payable, Other Payables [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [17] | 8.88% | ||||||
Pepco Holdings LLC [Member] | Tax-exempt Money Market Funds [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 112 | 112 | ||||||
Pepco Holdings LLC [Member] | Tax-exempt Money Market Funds [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 1.74% | |||||||
Pepco Holdings LLC [Member] | Tax-exempt Money Market Funds [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.40% | |||||||
Pepco Holdings LLC [Member] | Medium-term Notes [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 22 | 26 | ||||||
Pepco Holdings LLC [Member] | Medium-term Notes [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 7.61% | |||||||
Pepco Holdings LLC [Member] | Medium-term Notes [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 7.72% | |||||||
Pepco Holdings LLC [Member] | Transition Bonds [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [18] | $ 59 | 90 | |||||
Pepco Holdings LLC [Member] | Transition Bonds [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [18] | |||||||
Pepco Holdings LLC [Member] | Transition Bonds [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [18] | 5.55% | ||||||
Pepco Holdings LLC [Member] | Capital Lease Obligations [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Capital lease obligations, current | $ 14 | |||||||
Capital lease obligations, noncurrent | 27 | |||||||
Potomac Electric Power Company [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | 15 | |||||||
Long-term Debt, Gross | 2,751 | 2,570 | ||||||
Unamortized debt discount and premium, net | 2 | 2 | ||||||
Unamortized Debt Issuance Expense | (34) | (32) | ||||||
Long-term debt | 2,704 | 2,521 | ||||||
Long-term debt due within one year | (15) | (19) | ||||||
Long-term debt | 2,704 | 2,521 | ||||||
Due in 2019 | 14 | |||||||
2,020 | 0 | |||||||
2,021 | 1 | |||||||
Repayments of Long-term Debt | 14 | 13 | 11 | |||||
Potomac Electric Power Company [Member] | Secured Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [19] | $ 2,735 | 2,535 | |||||
Potomac Electric Power Company [Member] | Secured Debt [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [19] | 3.05% | ||||||
Potomac Electric Power Company [Member] | Secured Debt [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [19] | 7.90% | ||||||
Potomac Electric Power Company [Member] | Notes Payable, Other Payables [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [20] | $ 16 | 35 | |||||
Potomac Electric Power Company [Member] | Notes Payable, Other Payables [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [20] | 7.28% | ||||||
Potomac Electric Power Company [Member] | Notes Payable, Other Payables [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [20] | 8.88% | ||||||
Delmarva Power & Light Company [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | $ 91 | |||||||
Long-term Debt, Gross | 1,504 | 1,309 | ||||||
Unamortized debt discount and premium, net | 2 | 2 | ||||||
Unamortized Debt Issuance Expense | (12) | (11) | ||||||
Long-term debt due within one year | (79) | (79) | ||||||
Long-term debt | 1,403 | 1,217 | ||||||
Long-term debt due within one year | (91) | (83) | ||||||
Long-term debt | 1,403 | 1,217 | ||||||
2,020 | 0 | |||||||
2,021 | 0 | |||||||
Repayments of Long-term Debt | 4 | 40 | 100 | |||||
Delmarva Power & Light Company [Member] | Secured Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [21] | $ 1,370 | 1,171 | |||||
Delmarva Power & Light Company [Member] | Secured Debt [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [21] | 1.81% | ||||||
Delmarva Power & Light Company [Member] | Secured Debt [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [21] | 4.27% | ||||||
Delmarva Power & Light Company [Member] | Tax-exempt Money Market Funds [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 112 | 112 | ||||||
Delmarva Power & Light Company [Member] | Tax-exempt Money Market Funds [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 1.74% | |||||||
Delmarva Power & Light Company [Member] | Tax-exempt Money Market Funds [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 5.40% | |||||||
Delmarva Power & Light Company [Member] | Medium-term Notes [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | $ 22 | 26 | ||||||
Delmarva Power & Light Company [Member] | Medium-term Notes [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 7.61% | |||||||
Delmarva Power & Light Company [Member] | Medium-term Notes [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | 7.72% | |||||||
Atlantic City Electric Company [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | $ 18 | |||||||
Long-term Debt, Gross | 1,196 | 1,127 | ||||||
Unamortized debt discount and premium, net | (1) | (1) | ||||||
Unamortized Debt Issuance Expense | (7) | (5) | ||||||
Long-term debt | 1,170 | 840 | ||||||
Long-term debt due within one year | (18) | (281) | ||||||
Long-term debt | 1,170 | 840 | ||||||
2,020 | 20 | |||||||
2,021 | 260 | |||||||
Repayments of Long-term Debt | 281 | 35 | $ 48 | |||||
Atlantic City Electric Company [Member] | Secured Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Gross | [22] | $ 1,137 | 1,037 | |||||
Atlantic City Electric Company [Member] | Secured Debt [Member] | Minimum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [22] | 3.38% | ||||||
Atlantic City Electric Company [Member] | Secured Debt [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [22] | 6.80% | ||||||
Atlantic City Electric Company [Member] | Transition Bonds [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | $ 18 | |||||||
Long-term Debt, Gross | [23] | 59 | $ 90 | |||||
2,020 | 20 | |||||||
2,021 | $ 21 | |||||||
Atlantic City Electric Company [Member] | Transition Bonds [Member] | Maximum [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Debt Instrument, Interest Rate, Stated Percentage | [23] | 5.55% | ||||||
AGEPFNotesNov2017 [Member] | AGE Biomass project [Member] | Long-term Debt [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Repayments of Long-term Debt | $ 228 | |||||||
Subsequent Event [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Repayments of Debt | $ 300 | |||||||
Subsequent Event [Member] | Commonwealth Edison Co [Member] | ||||||||
Debt Instrument [Line Items] | ||||||||
Repayments of Debt | $ 300 | |||||||
[1] | In January 2019, $300 million of ComEd long-term debt due within one year was paid in full. | |||||||
[2] | Substantially all of ComEd’s assets other than expressly excepted property and substantially all of PECO’s, Pepco's, DPL's and ACE's assets are subject to the liens of their respective mortgage indentures. | |||||||
[3] | Includes capital lease obligations of $36 million and $53 million at December 31, 2018 and 2017, respectively. Lease payments of $21 million, $5 million, $1 million, $1 million, less than $1 million, and $8 million will be made in 2019, 2020, 2021, 2022, 2023, and thereafter, respectively. | |||||||
[4] | Includes financing related to Albany Green Energy, LLC (AGE). During the third quarter of 2017, Generation retired $228 million of its outstanding debt balance. | |||||||
[5] | Excludes interest on CEU Upstream nonrecourse debt, see discussion below. | |||||||
[6] | Amounts owed to these financing trusts are recorded as Long-term debt to financing trusts within Exelon’s Consolidated Balance Sheets. | |||||||
[7] | Includes Generation’s capital lease obligations of $14 million and $18 million at December 31, 2018 and 2017, respectively. Generation will make lease payments of $7 million, $5 million, $1 million, and $1 million in 2019, 2020, 2021, and 2022, respectively. Lease payments of less than $1 million annually will be made from 2023 through expiration of the final capital lease in 2024. | |||||||
[8] | Includes financing related to Albany Green Energy, LLC (AGE). During the third quarter of 2017, Generation retired $228 million of its outstanding debt balance. | |||||||
[9] | Excludes interest on CEU Upstream nonrecourse debt, see discussion below. | |||||||
[10] | In January 2019, the $300 million balance was paid in full. | |||||||
[11] | Substantially all of ComEd’s assets, other than expressly excepted property, are subject to the lien of its mortgage indenture. | |||||||
[12] | Includes ComEd’s capital lease obligations of $8 million at both December 31, 2018 and 2017, respectively. Lease payments of less than $1 million annually will be made from 2019 through expiration at 2053. | |||||||
[13] | Amount owed to this financing trust is recorded as Long-term debt to financing trust within ComEd’s Consolidated Balance Sheets. | |||||||
[14] | Amounts owed to this financing trust are recorded as Long-term debt to financing trusts within PECO’s Consolidated Balance Sheets. | |||||||
[15] | Substantially all of PECO’s assets are subject to the lien of its mortgage indenture. | |||||||
[16] | Substantially all of Pepco's, DPL's, and ACE's assets are subject to the lien of its respective mortgage indenture. | |||||||
[17] | Includes Pepco's capital lease obligations of $14 million and $27 million at December 31, 2018 and 2017, respectively. | |||||||
[18] | Transition bonds are recorded as part of Long-term debt within ACE's Consolidated Balance Sheets. | |||||||
[19] | Substantially all of Pepco's assets are subject to the lien of its respective mortgage indenture. | |||||||
[20] | Includes capital lease obligations of $14 million and $27 million at December 31, 2018 and 2017, respectively. Lease payments of $14 million will be made in 2019. | |||||||
[21] | Substantially all of DPL's assets are subject to the lien of its respective mortgage indenture. | |||||||
[22] | Substantially all of ACE's assets are subject to the lien of its respective mortgage indenture. | |||||||
[23] | Maturities of ACE's Transition Bonds outstanding at December 31, 2018 are $18 million in 2019, $20 million in 2020 and $21 million in 2021. |
Debt and Credit Agreements - Sc
Debt and Credit Agreements - Schedule of Long-term Debt Maturities (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Debt Instrument [Line Items] | |||
2,019 | $ 1,349 | ||
2,020 | 3,528 | ||
2,021 | 1,511 | ||
2,022 | 3,084 | ||
2,023 | 850 | ||
Thereafter | [1] | 24,979 | |
Total | 35,301 | ||
Long-term debt to financing trusts | 390 | $ 389 | |
ComEd Financing III Affiliate [Member] | |||
Debt Instrument [Line Items] | |||
Long-term debt to financing trusts | 206 | 205 | |
Exelon Generation Co L L C [Member] | |||
Debt Instrument [Line Items] | |||
2,019 | 906 | ||
2,020 | 2,108 | ||
2,021 | 1 | ||
2,022 | 1,024 | ||
2,023 | 0 | ||
Thereafter | 4,720 | ||
Total | 8,759 | ||
Commonwealth Edison Co [Member] | |||
Debt Instrument [Line Items] | |||
2,019 | 300 | ||
2,020 | 500 | ||
2,021 | 350 | ||
2,022 | 0 | ||
2,023 | 0 | ||
Thereafter | [2] | 7,243 | |
Total | 8,393 | ||
Long-term debt to financing trusts | 205 | 205 | |
Commonwealth Edison Co [Member] | ComEd Financing III Affiliate [Member] | |||
Debt Instrument [Line Items] | |||
Long-term debt to financing trusts | 205 | 205 | |
PECO Energy Co [Member] | |||
Debt Instrument [Line Items] | |||
2,019 | 0 | ||
2,020 | 0 | ||
2,021 | 300 | ||
2,022 | 350 | ||
2,023 | 50 | ||
Thereafter | [3] | 2,609 | |
Total | 3,309 | ||
Long-term debt to financing trusts | [4] | 184 | 184 |
Baltimore Gas and Electric Company [Member] | |||
Debt Instrument [Line Items] | |||
2,019 | 0 | ||
2,020 | 0 | ||
2,021 | 300 | ||
2,022 | 250 | ||
2,023 | 300 | ||
Thereafter | 2,050 | ||
Total | 2,900 | ||
Pepco Holdings LLC [Member] | |||
Debt Instrument [Line Items] | |||
2,019 | 125 | ||
2,020 | 20 | ||
2,021 | 261 | ||
2,022 | 310 | ||
2,023 | 500 | ||
Thereafter | 4,420 | ||
Total | 5,636 | ||
Potomac Electric Power Company [Member] | |||
Debt Instrument [Line Items] | |||
2,019 | 15 | ||
2,020 | 0 | ||
2,021 | 1 | ||
2,022 | 310 | ||
2,023 | 0 | ||
Thereafter | 2,425 | ||
Total | 2,751 | ||
Delmarva Power & Light Company [Member] | |||
Debt Instrument [Line Items] | |||
2,019 | 91 | ||
2,020 | 0 | ||
2,021 | 0 | ||
2,022 | 0 | ||
2,023 | 500 | ||
Thereafter | 913 | ||
Total | 1,504 | ||
Atlantic City Electric Company [Member] | |||
Debt Instrument [Line Items] | |||
2,019 | 18 | ||
2,020 | 20 | ||
2,021 | 260 | ||
2,022 | 0 | ||
2,023 | 0 | ||
Thereafter | 898 | ||
Total | 1,196 | ||
Capital Lease Obligations [Member] | |||
Debt Instrument [Line Items] | |||
Capital Leases, Future Minimum Payments Due Thereafter | 0 | ||
Capital Lease Obligations [Member] | Exelon Generation Co L L C [Member] | |||
Debt Instrument [Line Items] | |||
Capital Leases, Future Minimum Payments Due Thereafter | 0 | ||
Long-term Debt [Member] | |||
Debt Instrument [Line Items] | |||
Long-term debt to financing trusts | 390 | 390 | |
Long-term Debt [Member] | ComEd Financing III Affiliate [Member] | |||
Debt Instrument [Line Items] | |||
Long-term debt to financing trusts | [5] | 206 | 206 |
Long-term Debt [Member] | Commonwealth Edison Co [Member] | |||
Debt Instrument [Line Items] | |||
Long-term debt to financing trusts | 206 | 206 | |
Long-term Debt [Member] | Commonwealth Edison Co [Member] | ComEd Financing III Affiliate [Member] | |||
Debt Instrument [Line Items] | |||
Long-term debt to financing trusts | [6] | 206 | $ 206 |
Long-term Debt [Member] | PECO Energy Co [Member] | PECO Financing Trusts [Member] | |||
Debt Instrument [Line Items] | |||
Long-term debt to financing trusts | $ 184 | ||
Minimum [Member] | Tax-exempt Money Market Funds [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 1.74% | ||
Minimum [Member] | Tax-exempt Money Market Funds [Member] | Pepco Holdings LLC [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 1.74% | ||
Minimum [Member] | Tax-exempt Money Market Funds [Member] | Delmarva Power & Light Company [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 1.74% | ||
Maximum [Member] | Tax-exempt Money Market Funds [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.40% | ||
Maximum [Member] | Tax-exempt Money Market Funds [Member] | Pepco Holdings LLC [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.40% | ||
Maximum [Member] | Tax-exempt Money Market Funds [Member] | Delmarva Power & Light Company [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | 5.40% | ||
Maximum [Member] | Long-term Debt [Member] | ComEd Financing III Affiliate [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | [5] | 6.35% | |
Maximum [Member] | Long-term Debt [Member] | Commonwealth Edison Co [Member] | ComEd Financing III Affiliate [Member] | |||
Debt Instrument [Line Items] | |||
Debt Instrument, Interest Rate, Stated Percentage | [6] | 6.35% | |
[1] | Includes $390 million due to ComEd and PECO financing trusts. | ||
[2] | Includes $206 million due to ComEd financing trust. | ||
[3] | Includes $184 million due to PECO financing trusts. | ||
[4] | Amounts owed to this financing trust are recorded as Long-term debt to financing trusts within PECO’s Consolidated Balance Sheets. | ||
[5] | Amounts owed to these financing trusts are recorded as Long-term debt to financing trusts within Exelon’s Consolidated Balance Sheets. | ||
[6] | Amount owed to this financing trust is recorded as Long-term debt to financing trust within ComEd’s Consolidated Balance Sheets. |
Debt and Credit Agreements - Na
Debt and Credit Agreements - Narrative (Details) $ / shares in Units, shares in Millions | 12 Months Ended | |||||||||
Dec. 31, 2018USD ($)MW | Dec. 31, 2017USD ($)shares | Dec. 31, 2016USD ($)$ / shares | Dec. 30, 2018USD ($) | Jun. 30, 2018USD ($) | Mar. 31, 2016USD ($) | Oct. 23, 2015USD ($) | Jun. 30, 2014USD ($)$ / sharesshares | |||
Debt Instrument [Line Items] | ||||||||||
2,019 | $ 1,349,000,000 | |||||||||
Long-term Debt, Current Maturities | 1,349,000,000 | [1] | $ 2,088,000,000 | |||||||
Repayments of Long-term Debt | 1,786,000,000 | 2,490,000,000 | $ 1,936,000,000 | |||||||
Line of credit facility, maximum borrowing capacity | [2] | 9,704,000,000 | ||||||||
Outstanding letters of credit | 1,696,000,000 | |||||||||
Long-term debt, gross | 34,911,000,000 | 33,657,000,000 | ||||||||
Long-term debt | 35,301,000,000 | |||||||||
Collateral amount of debt | 3,000,000,000 | |||||||||
Outstanding borrowings/facility draws | 0 | |||||||||
Line of Credit Facility, Current Borrowing Capacity | $ 135,000,000 | 128,000,000 | ||||||||
Credit agreement threshold | 2.50 | |||||||||
Transition Bonds [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Long-term debt, gross | $ 59,000,000 | 90,000,000 | ||||||||
Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Long-term debt, gross | 11,285,000,000 | 11,285,000,000 | ||||||||
Junior Subordinated Debt [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Long-term debt, gross | $ 1,150,000,000 | $ 1,150,000,000 | ||||||||
Equity units issued | shares | 23 | |||||||||
Conversion price | $ / shares | $ 50 | |||||||||
Interest rate on long-term debt | 3.497% | 2.50% | ||||||||
Stock Issued During Period, Shares, Treasury Stock Reissued | shares | 33 | |||||||||
Junior Subordinated Notes | $ 1,150,000,000 | $ 1,150,000,000 | ||||||||
Loss on Reissuance, Treasury Stock | 1,050,000,000 | |||||||||
Maximum [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Basis points adders for prime-based borrowings | 90.00% | |||||||||
Basis points adders for LIBOR-based borrowings | 1.7 | |||||||||
Maximum [Member] | Transition Bonds [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 5.55% | |||||||||
Maximum [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 7.60% | |||||||||
Maximum [Member] | Junior Subordinated Debt [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 3.50% | |||||||||
Minimum [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 2.45% | |||||||||
Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | $ 500,000,000 | |||||||||
Exelon Corporate [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
2,019 | $ 0 | |||||||||
Repayments of Long-term Debt | 0 | 569,000,000 | 46,000,000 | |||||||
Outstanding letters of credit | 9,000,000 | |||||||||
Long-term debt, gross | 7,039,000,000 | 7,039,000,000 | ||||||||
Long-term debt | 7,039,000,000 | |||||||||
Outstanding borrowings/facility draws | 0 | |||||||||
Exelon Corporate [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Long-term debt, gross | [3] | 5,889,000,000 | 5,889,000,000 | |||||||
Exelon Corporate [Member] | Junior Subordinated Debt [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Long-term debt, gross | $ 1,150,000,000 | 1,150,000,000 | ||||||||
Exelon Corporate [Member] | Maximum [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | [3] | 7.60% | ||||||||
Exelon Corporate [Member] | Maximum [Member] | Junior Subordinated Debt [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 3.50% | |||||||||
Exelon Corporate [Member] | Minimum [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | [3] | 2.45% | ||||||||
Exelon Corporate [Member] | Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | [2] | $ 600,000,000 | ||||||||
Exelon Generation Co L L C [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
2,019 | 906,000,000 | |||||||||
Long-term Debt, Current Maturities | 906,000,000 | 346,000,000 | ||||||||
Repayments of Long-term Debt | 141,000,000 | 1,261,000,000 | 202,000,000 | |||||||
Line of credit facility, maximum borrowing capacity | 200,000,000 | $ 45,000,000 | ||||||||
Long-term debt, gross | 8,759,000,000 | 8,955,000,000 | ||||||||
Long-term debt | 8,759,000,000 | |||||||||
Line of Credit Facility, Current Borrowing Capacity | $ 49,000,000 | 49,000,000 | $ 75,000,000 | |||||||
Credit agreement threshold | 3 | |||||||||
Exelon Generation Co L L C [Member] | ExGen Texas Power [Member] | Interest Rate Swap [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 2.34% | |||||||||
Non-recourse debt, interest rate swap | $ 505,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Long-term debt, gross | 6,019,000,000 | 6,019,000,000 | ||||||||
Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Repayments of Long-term Debt | 31,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | ExGen Texas Power [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Debt Instrument, Face Amount | 675,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | DOE Project Financing, 3.092% January 2, 2037 [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Outstanding letters of credit | 38,000,000 | |||||||||
Non-recourse debt, commitment | $ 646,000,000 | |||||||||
Debt, Weighted Average Interest Rate | 2.82% | |||||||||
Non-recourse debt | $ 508,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | Denver International Airport [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 5.50% | |||||||||
Outstanding borrowings/facility draws | $ 7,000,000 | |||||||||
Non-recourse debt | $ 6,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | Holyoke [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 5.25% | |||||||||
Outstanding borrowings/facility draws | $ 11,000,000 | |||||||||
Non-recourse debt | 8,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | Upstream Gas Property [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Repayments of Long-term Debt | 15,000,000 | |||||||||
Escrow Deposit | 6,000,000 | |||||||||
Gain (Loss) on Sale of Debt Investments | 37,000,000 | |||||||||
Long-term debt | $ 15,000,000 | 15,000,000 | ||||||||
Outstanding borrowings/facility draws | 22,000,000 | |||||||||
Proceeds from Sales of Business, Affiliate and Productive Assets | 1,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | SolGen [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 3.93% | |||||||||
Debt Instrument, Face Amount | $ 150,000,000 | |||||||||
Non-recourse debt | $ 137,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | Renewable Power Generation [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 4.11% | |||||||||
Debt Instrument, Face Amount | $ 150,000,000 | |||||||||
Non-recourse debt | 115,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | Continetal Wind [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | 131,000,000 | |||||||||
Aggregate Bank Commitments Under Unsecured Revolving Credit Facilities | 10,000,000 | |||||||||
Outstanding letters of credit | $ 114,000,000 | |||||||||
Interest rate on long-term debt | 6.00% | |||||||||
Debt Instrument, Face Amount | $ 613,000,000 | |||||||||
Generation capacity of portfolio | MW | 667 | |||||||||
Non-recourse debt | $ 479,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Non Recourse Debt [Member] | ExGenRenewablesIVNov2024 [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 3.00% | |||||||||
Long-term debt | $ 850,000,000 | |||||||||
Non-recourse debt, interest rate swap | 636,000,000 | |||||||||
Non-recourse debt | $ 834,000,000 | |||||||||
Non-recourse debt, hedge percentage | 2.32% | |||||||||
Proceeds from Issuance of Debt | $ 785,000,000 | |||||||||
Proceeds from (Repayments of) Restricted Cash, Financing Activities | $ 50,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Maximum [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 7.60% | |||||||||
Exelon Generation Co L L C [Member] | Minimum [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 2.95% | |||||||||
Exelon Generation Co L L C [Member] | Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | [2] | $ 5,300,000,000 | ||||||||
Outstanding letters of credit | 1,203,000,000 | |||||||||
Outstanding borrowings/facility draws | 0 | |||||||||
Exelon Generation Co L L C [Member] | Line of Credit [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | [2] | 545,000,000 | ||||||||
Outstanding letters of credit | 353,000,000 | |||||||||
Outstanding borrowings/facility draws | 0 | |||||||||
Exelon Generation Co L L C [Member] | Domestic Line of Credit [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | 95,000,000 | $ 100,000,000 | ||||||||
Exelon Generation Co L L C [Member] | Line of Credit [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | 150,000,000 | |||||||||
Line of Credit Facility, Current Borrowing Capacity | 30,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Outstanding letters of credit | 545,000,000 | 480,000,000 | ||||||||
Commonwealth Edison Co [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
2,019 | 300,000,000 | |||||||||
Long-term Debt, Current Maturities | 300,000,000 | [4] | 840,000,000 | |||||||
Repayments of Long-term Debt | 840,000,000 | 425,000,000 | 665,000,000 | |||||||
Outstanding letters of credit | 2,000,000 | |||||||||
Long-term debt, gross | 8,187,000,000 | 7,676,000,000 | ||||||||
Long-term debt | 8,393,000,000 | |||||||||
Outstanding borrowings/facility draws | 0 | |||||||||
Line of Credit Facility, Current Borrowing Capacity | $ 33,000,000 | 34,000,000 | ||||||||
Credit agreement threshold | 2 | |||||||||
Commonwealth Edison Co [Member] | Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | [2] | $ 1,000,000,000 | ||||||||
PECO Energy Co [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
2,019 | 0 | |||||||||
Repayments of Long-term Debt | 500,000,000 | 0 | 300,000,000 | |||||||
Outstanding letters of credit | 0 | |||||||||
Long-term debt, gross | 3,125,000,000 | 2,925,000,000 | ||||||||
Long-term debt | 3,309,000,000 | |||||||||
Outstanding borrowings/facility draws | 0 | |||||||||
Line of Credit Facility, Current Borrowing Capacity | $ 34,000,000 | 34,000,000 | ||||||||
Credit agreement threshold | 2 | |||||||||
PECO Energy Co [Member] | Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | [2] | $ 600,000,000 | ||||||||
Baltimore Gas and Electric Company [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
2,019 | 0 | |||||||||
Repayments of Long-term Debt | 0 | 41,000,000 | $ 379,000,000 | |||||||
Outstanding letters of credit | 1,000,000 | |||||||||
Long-term debt, gross | 2,900,000,000 | 2,600,000,000 | ||||||||
Long-term debt | 2,900,000,000 | |||||||||
Outstanding borrowings/facility draws | 0 | |||||||||
Line of Credit Facility, Current Borrowing Capacity | $ 5,000,000 | 5,000,000 | ||||||||
Preferred Stock, Redemption Price Per Share | $ / shares | $ 100 | |||||||||
Credit agreement threshold | 2 | |||||||||
Baltimore Gas and Electric Company [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Long-term debt, gross | $ 2,900,000,000 | 2,600,000,000 | ||||||||
Baltimore Gas and Electric Company [Member] | Maximum [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 6.35% | |||||||||
Baltimore Gas and Electric Company [Member] | Minimum [Member] | Senior Notes [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | 2.40% | |||||||||
Baltimore Gas and Electric Company [Member] | Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | [2] | $ 600,000,000 | ||||||||
Pepco Holdings LLC [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
2,019 | 125,000,000 | |||||||||
Repayments of Long-term Debt | 299,000,000 | 169,000,000 | ||||||||
Long-term debt, gross | 5,636,000,000 | 5,189,000,000 | ||||||||
Long-term debt | 5,636,000,000 | |||||||||
Short-term Bank Loans and Notes Payable | $ 500,000,000 | |||||||||
Debt Instrument, Interest Rate Terms | LIBOR plus 1% | |||||||||
Pepco Holdings LLC [Member] | Transition Bonds [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Long-term debt, gross | [5] | $ 59,000,000 | 90,000,000 | |||||||
Pepco Holdings LLC [Member] | Maximum [Member] | Transition Bonds [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | [5] | 5.55% | ||||||||
Pepco Holdings LLC [Member] | Minimum [Member] | Transition Bonds [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | [5] | |||||||||
Pepco Holdings LLC [Member] | Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | $ 1,500,000,000 | |||||||||
Pepco Holdings LLC [Member] | Revolving Credit Facility [Member] | Maximum [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | 900,000,000 | |||||||||
Potomac Electric Power Company [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
2,019 | 15,000,000 | |||||||||
Repayments of Long-term Debt | 14,000,000 | 13,000,000 | $ 11,000,000 | |||||||
Outstanding letters of credit | 8,000,000 | |||||||||
Long-term debt, gross | 2,751,000,000 | 2,570,000,000 | ||||||||
Long-term debt | 2,751,000,000 | |||||||||
Outstanding borrowings/facility draws | 0 | |||||||||
Line of Credit Facility, Current Borrowing Capacity | $ 5,000,000 | 2,000,000 | ||||||||
Credit agreement threshold | 2 | |||||||||
Potomac Electric Power Company [Member] | Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | [2] | $ 300,000,000 | ||||||||
Delmarva Power & Light Company [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
2,019 | 91,000,000 | |||||||||
Long-term Debt, Current Maturities | 79,000,000 | 79,000,000 | ||||||||
Repayments of Long-term Debt | 4,000,000 | 40,000,000 | 100,000,000 | |||||||
Outstanding letters of credit | 1,000,000 | |||||||||
Long-term debt, gross | 1,504,000,000 | 1,309,000,000 | ||||||||
Long-term debt | 1,504,000,000 | |||||||||
Outstanding borrowings/facility draws | 0 | |||||||||
Line of Credit Facility, Current Borrowing Capacity | $ 5,000,000 | 2,000,000 | ||||||||
Credit agreement threshold | 2 | |||||||||
Delmarva Power & Light Company [Member] | Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | [2] | $ 300,000,000 | ||||||||
Delmarva Power & Light Company [Member] | Revolving Credit Facility [Member] | Maximum [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | 0 | |||||||||
Atlantic City Electric Company [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
2,019 | 18,000,000 | |||||||||
Repayments of Long-term Debt | 281,000,000 | 35,000,000 | $ 48,000,000 | |||||||
Outstanding letters of credit | 0 | |||||||||
Long-term debt, gross | 1,196,000,000 | 1,127,000,000 | ||||||||
Long-term debt | 1,196,000,000 | |||||||||
Outstanding borrowings/facility draws | 0 | |||||||||
Short-term Bank Loans and Notes Payable | $ 125,000,000 | |||||||||
Debt Instrument, Interest Rate Terms | LIBOR plus 0.55% | |||||||||
Line of Credit Facility, Current Borrowing Capacity | $ 5,000,000 | 2,000,000 | ||||||||
Credit agreement threshold | 2 | |||||||||
Atlantic City Electric Company [Member] | Transition Bonds [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
2,019 | $ 18,000,000 | |||||||||
Long-term debt, gross | [6] | $ 59,000,000 | $ 90,000,000 | |||||||
Atlantic City Electric Company [Member] | Maximum [Member] | Transition Bonds [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Interest rate on long-term debt | [6] | 5.55% | ||||||||
Atlantic City Electric Company [Member] | Revolving Credit Facility [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | [2] | $ 300,000,000 | ||||||||
Atlantic City Electric Company [Member] | Revolving Credit Facility [Member] | Maximum [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | 0 | |||||||||
Corporate, Non-Segment [Member] | Exelon Corporate [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Short-term Bank Loans and Notes Payable | $ 500,000,000 | |||||||||
Debt Instrument, Interest Rate Terms | LIBOR plus 1% | |||||||||
CENG [Member] | Exelon Generation Co L L C [Member] | Domestic Line of Credit [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | $ 200,000,000 | |||||||||
CENG [Member] | Exelon Generation Co L L C [Member] | Line of Credit [Member] | ||||||||||
Debt Instrument [Line Items] | ||||||||||
Line of credit facility, maximum borrowing capacity | $ 100,000,000 | |||||||||
[1] | In January 2019, $300 million of ComEd long-term debt due within one year was paid in full. | |||||||||
[2] | Excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million, $33 million, $34 million, $5 million, $5 million, $5 million and $5 million, respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. As of December 31, 2018, letters of credit issued under these facilities totaled $5 million and $2 million for Generation and BGE, respectively. | |||||||||
[3] | Senior unsecured notes include mirror debt that is held on both Generation and Exelon Corporation's balance sheets. | |||||||||
[4] | In January 2019, the $300 million balance was paid in full. | |||||||||
[5] | Transition bonds are recorded as part of Long-term debt within ACE's Consolidated Balance Sheets. | |||||||||
[6] | Maturities of ACE's Transition Bonds outstanding at December 31, 2018 are $18 million in 2019, $20 million in 2020 and $21 million in 2021. |
Income Taxes Deferred Tax Revis
Income Taxes Deferred Tax Revision (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2017 | Dec. 31, 2018 | ||
Regulatory Liabilities | $ 10,388 | $ 10,203 | |
Remeasurement Of Deferred Income Taxes DueTo Tax Reform [Member] | |||
Increase (Decrease) in Other Deferred Liability | [1] | 8,624 | |
Regulatory Liabilities | [2] | 7,315 | |
Deferred Income Tax Expense (Benefit) | [1] | 1,309 | |
Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To IRS Normalization Rules [Member] | |||
Regulatory Liabilities | 3,040 | ||
Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To Rate Regulator Determinations [Member] | |||
Regulatory Liabilities | 1,694 | ||
Net Regulatory Liabilities Associated With Ultimate Settlement To Customers [Member] | |||
Regulatory Liabilities | 4,734 | ||
Exelon Generation Co L L C [Member] | Remeasurement Of Deferred Income Taxes DueTo Tax Reform [Member] | |||
Increase (Decrease) in Other Deferred Liability | 1,895 | ||
Deferred Income Tax Expense (Benefit) | 1,895 | ||
Commonwealth Edison Co [Member] | |||
Regulatory Liabilities | 6,577 | 6,343 | |
Commonwealth Edison Co [Member] | Remeasurement Of Deferred Income Taxes DueTo Tax Reform [Member] | |||
Increase (Decrease) in Other Deferred Liability | 2,819 | ||
Regulatory Liabilities | [2] | 2,818 | |
Deferred Income Tax Expense (Benefit) | 1 | ||
Commonwealth Edison Co [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To IRS Normalization Rules [Member] | |||
Regulatory Liabilities | 1,400 | ||
Commonwealth Edison Co [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To Rate Regulator Determinations [Member] | |||
Regulatory Liabilities | 573 | ||
Commonwealth Edison Co [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers [Member] | |||
Regulatory Liabilities | 1,973 | ||
PECO Energy Co [Member] | |||
Regulatory Liabilities | 690 | 596 | |
PECO Energy Co [Member] | Remeasurement Of Deferred Income Taxes DueTo Tax Reform [Member] | |||
Increase (Decrease) in Other Deferred Liability | 1,407 | ||
Regulatory Liabilities | [2] | 1,394 | |
Deferred Income Tax Expense (Benefit) | 13 | ||
PECO Energy Co [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To IRS Normalization Rules [Member] | |||
Regulatory Liabilities | [3] | 533 | |
PECO Energy Co [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To Rate Regulator Determinations [Member] | |||
Regulatory Liabilities | [3] | 43 | |
PECO Energy Co [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers [Member] | |||
Regulatory Liabilities | [3] | 576 | |
Baltimore Gas and Electric Company [Member] | |||
Regulatory Liabilities | 1,163 | 1,269 | |
Baltimore Gas and Electric Company [Member] | Remeasurement Of Deferred Income Taxes DueTo Tax Reform [Member] | |||
Increase (Decrease) in Other Deferred Liability | 1,120 | ||
Regulatory Liabilities | [2] | 1,124 | |
Deferred Income Tax Expense (Benefit) | (4) | ||
Baltimore Gas and Electric Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To IRS Normalization Rules [Member] | |||
Regulatory Liabilities | 459 | ||
Baltimore Gas and Electric Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To Rate Regulator Determinations [Member] | |||
Regulatory Liabilities | 324 | ||
Baltimore Gas and Electric Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers [Member] | |||
Regulatory Liabilities | 783 | ||
Pepco Holdings LLC [Member] | |||
Regulatory Liabilities | 1,928 | 1,948 | |
Pepco Holdings LLC [Member] | Remeasurement Of Deferred Income Taxes DueTo Tax Reform [Member] | |||
Increase (Decrease) in Other Deferred Liability | 1,944 | ||
Regulatory Liabilities | [2] | 1,979 | |
Deferred Income Tax Expense (Benefit) | (35) | ||
Pepco Holdings LLC [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To IRS Normalization Rules [Member] | |||
Regulatory Liabilities | 648 | ||
Pepco Holdings LLC [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To Rate Regulator Determinations [Member] | |||
Regulatory Liabilities | 754 | ||
Pepco Holdings LLC [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers [Member] | |||
Regulatory Liabilities | 1,402 | ||
Potomac Electric Power Company [Member] | |||
Regulatory Liabilities | 832 | 829 | |
Potomac Electric Power Company [Member] | Remeasurement Of Deferred Income Taxes DueTo Tax Reform [Member] | |||
Increase (Decrease) in Other Deferred Liability | 968 | ||
Regulatory Liabilities | [2] | 976 | |
Deferred Income Tax Expense (Benefit) | (8) | ||
Potomac Electric Power Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To IRS Normalization Rules [Member] | |||
Regulatory Liabilities | 299 | ||
Potomac Electric Power Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To Rate Regulator Determinations [Member] | |||
Regulatory Liabilities | 391 | ||
Potomac Electric Power Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers [Member] | |||
Regulatory Liabilities | 690 | ||
Delmarva Power & Light Company [Member] | |||
Regulatory Liabilities | 635 | 665 | |
Delmarva Power & Light Company [Member] | Remeasurement Of Deferred Income Taxes DueTo Tax Reform [Member] | |||
Increase (Decrease) in Other Deferred Liability | 540 | ||
Regulatory Liabilities | [2] | 545 | |
Deferred Income Tax Expense (Benefit) | (5) | ||
Delmarva Power & Light Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To IRS Normalization Rules [Member] | |||
Regulatory Liabilities | 195 | ||
Delmarva Power & Light Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To Rate Regulator Determinations [Member] | |||
Regulatory Liabilities | 194 | ||
Delmarva Power & Light Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers [Member] | |||
Regulatory Liabilities | 389 | ||
Atlantic City Electric Company [Member] | |||
Regulatory Liabilities | 422 | $ 420 | |
Atlantic City Electric Company [Member] | Remeasurement Of Deferred Income Taxes DueTo Tax Reform [Member] | |||
Increase (Decrease) in Other Deferred Liability | 456 | ||
Regulatory Liabilities | [2] | 458 | |
Deferred Income Tax Expense (Benefit) | (2) | ||
Atlantic City Electric Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To IRS Normalization Rules [Member] | |||
Regulatory Liabilities | 153 | ||
Atlantic City Electric Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers Subject To Rate Regulator Determinations [Member] | |||
Regulatory Liabilities | 170 | ||
Atlantic City Electric Company [Member] | Net Regulatory Liabilities Associated With Ultimate Settlement To Customers [Member] | |||
Regulatory Liabilities | $ 323 | ||
[1] | Amounts do not sum across due to deferred tax adjustments recorded at the Exelon Corporation parent company, primarily related to certain employee compensation plans. | ||
[2] | Reflects the net regulatory liabilities recorded on a pre-tax basis before taking into consideration the income tax benefits associated with the ultimate settlement with customers. | ||
[3] | Given the regulatory treatment of income tax benefits related to electric and gas distribution repairs, PECO was in an overall net regulatory asset position as of December 31, 2017 after recording the impacts related to the TCJA. As a result, the amount of customer benefits resulting from the TCJA subject to the discretion of PECO's rate regulators are lower relative to the other Utility Registrants. |
Income Taxes - Components of In
Income Taxes - Components of Income Tax Expense (Benefit) from Continuing Operations (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||
Dec. 31, 2018 | Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Income Taxes [Line Items] | ||||||
Income taxes | $ 26 | $ 120 | $ (126) | $ 753 | ||
Exelon Generation Co L L C [Member] | ||||||
Income Taxes [Line Items] | ||||||
Income taxes | (108) | (1,376) | 282 | |||
Commonwealth Edison Co [Member] | ||||||
Income Taxes [Line Items] | ||||||
Income taxes | 168 | 417 | 301 | |||
PECO Energy Co [Member] | ||||||
Income Taxes [Line Items] | ||||||
Income taxes | 6 | 104 | 149 | |||
Baltimore Gas and Electric Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Income taxes | 74 | 218 | 174 | |||
Potomac Electric Power Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Income taxes | 13 | 105 | 41 | |||
Delmarva Power & Light Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Income taxes | 22 | 71 | 22 | |||
Atlantic City Electric Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Income taxes | 12 | 26 | (4) | |||
Pepco Holdings LLC [Member] | ||||||
Income Taxes [Line Items] | ||||||
Income taxes | 35 | 217 | ||||
Pepco Holdings LLC [Member] | Successor [Member] | ||||||
Income Taxes [Line Items] | ||||||
Income taxes | $ 3 | |||||
Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||
Income Taxes [Line Items] | ||||||
Income taxes | $ 17 | |||||
Internal Revenue Service (IRS) [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 226 | 194 | 60 | |||
Deferred | (98) | (471) | 600 | |||
Investment Tax Credit | (24) | (25) | (24) | |||
Internal Revenue Service (IRS) [Member] | Exelon Generation Co L L C [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 337 | 584 | 513 | |||
Deferred | (347) | (2,005) | (254) | |||
Investment Tax Credit | (21) | (21) | (20) | |||
Internal Revenue Service (IRS) [Member] | Commonwealth Edison Co [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | (63) | (191) | (135) | |||
Deferred | 145 | 523 | 379 | |||
Investment Tax Credit | (2) | (2) | (2) | |||
Internal Revenue Service (IRS) [Member] | PECO Energy Co [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 11 | 71 | 63 | |||
Deferred | 10 | 28 | 72 | |||
Investment Tax Credit | 0 | 0 | 0 | |||
Internal Revenue Service (IRS) [Member] | Baltimore Gas and Electric Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | (5) | 74 | 51 | |||
Deferred | 47 | 101 | 88 | |||
Investment Tax Credit | 0 | (1) | (1) | |||
Internal Revenue Service (IRS) [Member] | Potomac Electric Power Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 28 | (20) | (118) | |||
Deferred | (21) | 114 | 136 | |||
Investment Tax Credit | 0 | 0 | 0 | |||
Internal Revenue Service (IRS) [Member] | Delmarva Power & Light Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | (3) | (24) | (88) | |||
Deferred | 13 | 82 | 97 | |||
Investment Tax Credit | 0 | 0 | 0 | |||
Internal Revenue Service (IRS) [Member] | Atlantic City Electric Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | (14) | (12) | (26) | |||
Deferred | 18 | 34 | 22 | |||
Investment Tax Credit | 0 | 0 | 0 | |||
Internal Revenue Service (IRS) [Member] | Pepco Holdings LLC [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | (4) | (60) | ||||
Deferred | 24 | 250 | ||||
Investment Tax Credit | (1) | (1) | ||||
Internal Revenue Service (IRS) [Member] | Pepco Holdings LLC [Member] | Successor [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | (281) | |||||
Deferred | 283 | |||||
Investment Tax Credit | (1) | |||||
Internal Revenue Service (IRS) [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 0 | |||||
Deferred | 10 | |||||
Investment Tax Credit | 0 | |||||
State and Local Jurisdiction [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | (1) | 14 | 39 | |||
Deferred | 17 | 162 | 78 | |||
State and Local Jurisdiction [Member] | Exelon Generation Co L L C [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 6 | 65 | 45 | |||
Deferred | (83) | 1 | (2) | |||
State and Local Jurisdiction [Member] | Commonwealth Edison Co [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | (29) | (49) | (4) | |||
Deferred | 117 | 136 | 63 | |||
State and Local Jurisdiction [Member] | PECO Energy Co [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 1 | 14 | 9 | |||
Deferred | (16) | (9) | 5 | |||
State and Local Jurisdiction [Member] | Baltimore Gas and Electric Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 0 | (5) | 5 | |||
Deferred | 32 | 49 | 31 | |||
State and Local Jurisdiction [Member] | Potomac Electric Power Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 0 | (2) | 7 | |||
Deferred | 6 | 13 | 16 | |||
State and Local Jurisdiction [Member] | Delmarva Power & Light Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 0 | 0 | 1 | |||
Deferred | 12 | 13 | 12 | |||
State and Local Jurisdiction [Member] | Atlantic City Electric Company [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 0 | 0 | 0 | |||
Deferred | 8 | 4 | $ 0 | |||
State and Local Jurisdiction [Member] | Pepco Holdings LLC [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 7 | (4) | ||||
Deferred | $ 9 | $ 32 | ||||
State and Local Jurisdiction [Member] | Pepco Holdings LLC [Member] | Successor [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | (11) | |||||
Deferred | $ 13 | |||||
State and Local Jurisdiction [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||
Income Taxes [Line Items] | ||||||
Current | 0 | |||||
Deferred | $ 7 |
Income Taxes - Reconciliation t
Income Taxes - Reconciliation to Effective Tax Rate (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||||||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | 21.00% | 35.00% | 35.00% | ||||||
State income taxes, net of Federal income tax benefit | 0.60% | 2.30% | 3.30% | [1] | |||||
Qualified nuclear decommissioning trust fund income | (1.90%) | 3.80% | 3.40% | ||||||
Amortization of investment tax credit, including deferred taxes on basis difference | (1.20%) | (0.90%) | (1.20%) | ||||||
Plant basis differences | (3.50%) | [2] | (1.70%) | (4.90%) | |||||
Production tax credits and other credits | (2.20%) | (1.80%) | (3.60%) | ||||||
Noncontrolling interests | (1.00%) | (0.20%) | |||||||
Like-Kind Exchange | (8.30%) | (1.20%) | |||||||
Statute of limitations expiration | (0.40%) | ||||||||
Penalties | 1.90% | ||||||||
Merger expenses | (3.60%) | 5.60% | |||||||
FitzPatrick bargain purchase gain | (2.20%) | ||||||||
Tax Cuts and Jobs Act of 2017 | [3] | 0.90% | (33.10%) | ||||||
Other | 1.00% | 0.10% | (0.70%) | [4] | |||||
Effective income tax rate | 5.40% | (3.30%) | 38.20% | ||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | $ 35 | ||||||||
Exelon Generation Co L L C [Member] | |||||||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | 21.00% | 35.00% | 35.00% | ||||||
State income taxes, net of Federal income tax benefit | (16.60%) | 2.90% | 3.20% | [1] | |||||
Qualified nuclear decommissioning trust fund income | (11.80%) | 9.90% | 7.90% | ||||||
Amortization of investment tax credit, including deferred taxes on basis difference | (6.50%) | (2.10%) | (2.30%) | ||||||
Plant basis differences | (0.00%) | [2] | (0.00%) | [2] | (0.00%) | ||||
Production tax credits and other credits | (13.50%) | (4.70%) | (8.30%) | ||||||
Noncontrolling interests | (6.10%) | (0.60%) | |||||||
Like-Kind Exchange | 0.00% | 0.00% | |||||||
Statute of limitations expiration | (1.70%) | ||||||||
Penalties | 0.00% | ||||||||
Merger expenses | (1.20%) | 1.10% | |||||||
FitzPatrick bargain purchase gain | (5.60%) | ||||||||
Tax Cuts and Jobs Act of 2017 | [3] | 2.70% | (128.30%) | ||||||
Other | 1.30% | (0.50%) | (1.40%) | [4] | |||||
Effective income tax rate | (29.50%) | (94.60%) | 32.90% | ||||||
Commonwealth Edison Co [Member] | |||||||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | 21.00% | 35.00% | 35.00% | ||||||
State income taxes, net of Federal income tax benefit | 8.30% | 5.70% | 5.60% | [1] | |||||
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | ||||||
Amortization of investment tax credit, including deferred taxes on basis difference | (0.20%) | (0.20%) | (0.30%) | ||||||
Plant basis differences | (0.20%) | [2] | 0.30% | [2] | (0.60%) | ||||
Production tax credits and other credits | (0.00%) | (0.00%) | (0.00%) | ||||||
Noncontrolling interests | (0.00%) | (0.00%) | |||||||
Like-Kind Exchange | (9.10%) | 1.30% | |||||||
Statute of limitations expiration | 0.00% | ||||||||
Penalties | 4.50% | ||||||||
Merger expenses | 0.00% | 0.00% | |||||||
FitzPatrick bargain purchase gain | 0.00% | ||||||||
Tax Cuts and Jobs Act of 2017 | [3] | (0.10%) | 0.10% | ||||||
Other | 0.50% | 0.20% | 0.10% | [4] | |||||
Effective income tax rate | 20.20% | 42.40% | 44.30% | ||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | $ 3 | ||||||||
PECO Energy Co [Member] | |||||||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | 21.00% | 35.00% | 35.00% | ||||||
State income taxes, net of Federal income tax benefit | (2.60%) | 0.60% | 1.30% | [1] | |||||
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | ||||||
Amortization of investment tax credit, including deferred taxes on basis difference | (0.10%) | (0.10%) | (0.10%) | ||||||
Plant basis differences | (14.10%) | [2] | (13.80%) | [2] | (9.60%) | ||||
Production tax credits and other credits | (0.00%) | (0.00%) | (0.00%) | ||||||
Noncontrolling interests | (0.00%) | (0.00%) | |||||||
Like-Kind Exchange | (3.20%) | 0.00% | |||||||
Statute of limitations expiration | 0.00% | ||||||||
Penalties | 0.00% | ||||||||
Merger expenses | 0.00% | 0.00% | |||||||
FitzPatrick bargain purchase gain | 0.00% | ||||||||
Tax Cuts and Jobs Act of 2017 | [3] | 0.00% | (2.30%) | ||||||
Other | 0.30% | (0.10%) | (1.20%) | [4] | |||||
Effective income tax rate | 1.30% | 19.30% | 25.40% | ||||||
Baltimore Gas and Electric Company [Member] | |||||||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | 21.00% | 35.00% | 35.00% | ||||||
State income taxes, net of Federal income tax benefit | 6.60% | 5.40% | 5.00% | [1] | |||||
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | ||||||
Amortization of investment tax credit, including deferred taxes on basis difference | (0.10%) | (0.10%) | (0.10%) | ||||||
Plant basis differences | (1.30%) | [2] | 0.10% | [2] | (2.70%) | ||||
Production tax credits and other credits | (0.00%) | (0.00%) | (0.00%) | ||||||
Noncontrolling interests | (0.00%) | (0.00%) | |||||||
Like-Kind Exchange | (8.00%) | 0.00% | |||||||
Statute of limitations expiration | 0.00% | ||||||||
Penalties | 0.00% | ||||||||
Merger expenses | 0.00% | 0.00% | |||||||
FitzPatrick bargain purchase gain | 0.00% | ||||||||
Tax Cuts and Jobs Act of 2017 | [3] | 0.00% | 0.90% | ||||||
Other | 0.90% | 0.20% | 0.00% | [4] | |||||
Effective income tax rate | 19.10% | 41.50% | 37.20% | ||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | $ 5 | ||||||||
Potomac Electric Power Company [Member] | |||||||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | 21.00% | 35.00% | 35.00% | ||||||
State income taxes, net of Federal income tax benefit | 2.20% | 3.20% | 15.70% | [1] | |||||
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | ||||||
Amortization of investment tax credit, including deferred taxes on basis difference | (0.10%) | (0.10%) | (0.20%) | ||||||
Plant basis differences | (2.70%) | [2] | (0.40%) | [2] | (22.80%) | ||||
Production tax credits and other credits | (0.00%) | (0.00%) | (0.00%) | ||||||
Noncontrolling interests | (0.00%) | (0.00%) | |||||||
Like-Kind Exchange | (14.80%) | 0.00% | |||||||
Statute of limitations expiration | 0.00% | ||||||||
Penalties | 0.00% | ||||||||
Merger expenses | (6.30%) | 23.50% | |||||||
FitzPatrick bargain purchase gain | 0.00% | ||||||||
Tax Cuts and Jobs Act of 2017 | [3] | 0.00% | 2.70% | ||||||
Other | 0.20% | (0.20%) | (1.80%) | [4] | |||||
Effective income tax rate | 5.80% | 33.90% | 49.40% | ||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | $ 14 | ||||||||
Delmarva Power & Light Company [Member] | |||||||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | 21.00% | 35.00% | 35.00% | [5] | |||||
State income taxes, net of Federal income tax benefit | 6.70% | 5.40% | 52.70% | [1],[5] | |||||
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | [5] | |||||
Amortization of investment tax credit, including deferred taxes on basis difference | (0.30%) | (0.20%) | (3.70%) | [5] | |||||
Plant basis differences | (0.30%) | [2] | 2.00% | [2] | (25.50%) | [5] | |||
Production tax credits and other credits | (0.00%) | (0.00%) | (0.00%) | [5] | |||||
Noncontrolling interests | (0.00%) | (0.00%) | [5] | ||||||
Like-Kind Exchange | (12.00%) | 0.00% | |||||||
Statute of limitations expiration | [5] | 0.00% | |||||||
Penalties | [5] | 0.00% | |||||||
Merger expenses | (7.80%) | 112.90% | [5] | ||||||
FitzPatrick bargain purchase gain | 0.00% | ||||||||
Tax Cuts and Jobs Act of 2017 | [3] | 0.00% | 2.50% | ||||||
Other | 0.40% | 0.10% | (2.20%) | [4],[5] | |||||
Effective income tax rate | 15.50% | 37.00% | 169.20% | [5] | |||||
Amount of Impairment to Carrying Amount of Regulatory Assets | $ 6 | ||||||||
Atlantic City Electric Company [Member] | |||||||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | 21.00% | 35.00% | 35.00% | [5] | |||||
State income taxes, net of Federal income tax benefit | 7.40% | 5.60% | 6.20% | [1],[5] | |||||
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | 0.00% | [5] | |||||
Amortization of investment tax credit, including deferred taxes on basis difference | (0.40%) | (0.40%) | 0.80% | [5] | |||||
Plant basis differences | (0.50%) | [2] | 3.60% | [2] | 10.30% | [5] | |||
Production tax credits and other credits | (0.00%) | (0.00%) | (0.00%) | [5] | |||||
Noncontrolling interests | (0.00%) | (0.00%) | [5] | ||||||
Like-Kind Exchange | (14.90%) | 0.00% | |||||||
Statute of limitations expiration | [5] | 0.00% | |||||||
Penalties | [5] | 0.00% | |||||||
Merger expenses | (19.80%) | (44.90%) | [5] | ||||||
FitzPatrick bargain purchase gain | 0.00% | ||||||||
Tax Cuts and Jobs Act of 2017 | [3] | 0.00% | 1.60% | ||||||
Other | 1.20% | (0.40%) | 1.30% | [4],[5] | |||||
Effective income tax rate | 13.80% | 25.20% | 8.70% | [5] | |||||
Amount of Impairment to Carrying Amount of Regulatory Assets | $ 7 | ||||||||
Pepco Holdings LLC [Member] | |||||||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | 21.00% | 35.00% | |||||||
State income taxes, net of Federal income tax benefit | 3.00% | 4.80% | |||||||
Qualified nuclear decommissioning trust fund income | 0.00% | 0.00% | |||||||
Amortization of investment tax credit, including deferred taxes on basis difference | (0.20%) | (0.20%) | |||||||
Plant basis differences | [2] | (1.60%) | 1.10% | ||||||
Production tax credits and other credits | (0.00%) | (0.00%) | |||||||
Noncontrolling interests | (0.00%) | ||||||||
Like-Kind Exchange | (14.50%) | 0.00% | |||||||
Merger expenses | (9.50%) | ||||||||
FitzPatrick bargain purchase gain | 0.00% | ||||||||
Tax Cuts and Jobs Act of 2017 | [3] | 0.10% | 6.40% | ||||||
Other | 0.30% | (0.10%) | |||||||
Effective income tax rate | 8.10% | 37.50% | |||||||
Amount of Impairment to Carrying Amount of Regulatory Assets | $ 27 | ||||||||
Pepco Holdings LLC [Member] | Successor [Member] | |||||||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | [5] | 35.00% | |||||||
State income taxes, net of Federal income tax benefit | [1],[5] | 5.80% | |||||||
Qualified nuclear decommissioning trust fund income | [5] | 0.00% | |||||||
Amortization of investment tax credit, including deferred taxes on basis difference | [5] | 1.40% | |||||||
Plant basis differences | [5] | 39.00% | |||||||
Production tax credits and other credits | [5] | (0.00%) | |||||||
Noncontrolling interests | [5] | (0.00%) | |||||||
Statute of limitations expiration | [5] | 0.00% | |||||||
Penalties | [5] | (0.70%) | |||||||
Merger expenses | [5] | (89.00%) | |||||||
Other | [4],[5] | 3.30% | |||||||
Effective income tax rate | [5] | (5.20%) | |||||||
Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||
Effective Income Tax Rate Reconciliation At Federal Statutory Income Tax Rate [Line Items] | |||||||||
U.S. Federal statutory rate | 35.00% | ||||||||
State income taxes, net of Federal income tax benefit | [1] | 11.90% | |||||||
Qualified nuclear decommissioning trust fund income | 0.00% | ||||||||
Amortization of investment tax credit, including deferred taxes on basis difference | (0.90%) | ||||||||
Plant basis differences | (13.50%) | ||||||||
Production tax credits and other credits | (0.00%) | ||||||||
Noncontrolling interests | (0.00%) | ||||||||
Statute of limitations expiration | 0.00% | ||||||||
Penalties | 0.00% | ||||||||
Merger expenses | 11.10% | ||||||||
Other | [4] | 3.60% | |||||||
Effective income tax rate | 47.20% | ||||||||
[1] | Includes a remeasurement of uncertain state income tax positions for Pepco and DPL. | ||||||||
[2] | Includes the charges related to the transmission-related income tax regulatory asset for Exelon, ComEd, BGE, PHI, Pepco, DPL and ACE of $35 million, $3 million, $5 million, $27 million, $14 million, $6 million and $7 million, respectively. See Note 4 - Regulatory Matters for additional information. | ||||||||
[3] | Included are impacts for TCJA other than the corporate rate change, including revisions further limiting tax deductions for compensation of certain highest paid executives, the write-off of foreign tax credit carryforwards, and loss of a 2015 domestic production activities deduction due to an NOL carryback. | ||||||||
[4] | At PECO, includes a cumulative adjustment related to an anticipated gas repairs tax return accounting method change. The method change request was filed and accepted in 2017. No change to the results recorded as of December 31, 2016 | ||||||||
[5] | DPL and ACE recognized a loss before income taxes for the year ended December 31, 2016, and PHI recognized a loss before income taxes for the period of March 24, 2016, through December 31, 2016. As a result, positive percentages represent an income tax benefit for the periods presented. |
Income Taxes - Tax Effects of T
Income Taxes - Tax Effects of Temporary Differences and Carryforwards (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 |
Operating Loss Carryforwards [Line Items] | ||
Plant basis differences | $ (12,533) | $ (12,490) |
Deferred Tax Liabilities, Other Finite-Lived Assets | 117 | 150 |
Derivatives and other financial instruments | 89 | (85) |
Deferred pension and postretirement obligation | 1,435 | 1,463 |
Deferred Tax Liabilities, Investments | (351) | (553) |
Deferred debt refinancing costs | 234 | 217 |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | (749) | (688) |
Tax loss carryforward | 237 | 344 |
Tax credit carryforward | 811 | 861 |
Investment in partnerships | (797) | (434) |
Other, net | 934 | 746 |
Deferred income tax liabilities (net) | (10,573) | (10,469) |
Unamortized investment tax credits | (724) | (732) |
Total deferred income tax liabilities (net) and unamortized investment tax credits | (11,297) | (11,201) |
Exelon Generation Co L L C [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Plant basis differences | (2,495) | (2,819) |
Deferred Tax Liabilities, Other Finite-Lived Assets | (44) | (66) |
Derivatives and other financial instruments | 35 | (66) |
Deferred pension and postretirement obligation | (188) | (205) |
Deferred Tax Liabilities, Investments | (351) | (553) |
Deferred debt refinancing costs | 23 | 26 |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | 0 | 0 |
Tax loss carryforward | 78 | 76 |
Tax credit carryforward | 816 | 868 |
Investment in partnerships | (775) | (416) |
Other, net | 239 | 78 |
Deferred income tax liabilities (net) | (2,662) | (3,077) |
Unamortized investment tax credits | (700) | (705) |
Total deferred income tax liabilities (net) and unamortized investment tax credits | (3,362) | (3,782) |
Commonwealth Edison Co [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Plant basis differences | (4,059) | (3,825) |
Deferred Tax Liabilities, Other Finite-Lived Assets | 0 | 0 |
Derivatives and other financial instruments | 69 | (2) |
Deferred pension and postretirement obligation | (255) | (285) |
Deferred Tax Liabilities, Investments | 0 | 0 |
Deferred debt refinancing costs | (7) | (8) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | 300 | 489 |
Tax loss carryforward | 0 | 33 |
Tax credit carryforward | 0 | 1 |
Investment in partnerships | 0 | 0 |
Other, net | 151 | 141 |
Deferred income tax liabilities (net) | (3,801) | (3,456) |
Unamortized investment tax credits | (12) | (13) |
Total deferred income tax liabilities (net) and unamortized investment tax credits | (3,813) | (3,469) |
PECO Energy Co [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Plant basis differences | (1,862) | (1,762) |
Deferred Tax Liabilities, Other Finite-Lived Assets | 0 | 0 |
Derivatives and other financial instruments | 0 | 0 |
Deferred pension and postretirement obligation | (26) | (15) |
Deferred Tax Liabilities, Investments | 0 | 0 |
Deferred debt refinancing costs | 0 | (1) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | (129) | (90) |
Tax loss carryforward | 18 | 9 |
Tax credit carryforward | 0 | 0 |
Investment in partnerships | 0 | 0 |
Other, net | 67 | 71 |
Deferred income tax liabilities (net) | (1,932) | (1,788) |
Unamortized investment tax credits | (1) | (1) |
Total deferred income tax liabilities (net) and unamortized investment tax credits | (1,933) | (1,789) |
Baltimore Gas and Electric Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Plant basis differences | (1,399) | (1,368) |
Deferred Tax Liabilities, Other Finite-Lived Assets | 0 | 0 |
Derivatives and other financial instruments | 0 | 0 |
Deferred pension and postretirement obligation | (26) | (29) |
Deferred Tax Liabilities, Investments | 0 | 0 |
Deferred debt refinancing costs | (3) | (3) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | 172 | 136 |
Tax loss carryforward | 25 | 11 |
Tax credit carryforward | 0 | 0 |
Investment in partnerships | 0 | 0 |
Other, net | 12 | 13 |
Deferred income tax liabilities (net) | (1,219) | (1,240) |
Unamortized investment tax credits | (3) | (4) |
Total deferred income tax liabilities (net) and unamortized investment tax credits | (1,222) | (1,244) |
Pepco Holdings LLC [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Plant basis differences | (2,577) | (2,521) |
Deferred Tax Liabilities, Other Finite-Lived Assets | 161 | 216 |
Derivatives and other financial instruments | 3 | 3 |
Deferred pension and postretirement obligation | (102) | (130) |
Deferred Tax Liabilities, Investments | 0 | 0 |
Deferred debt refinancing costs | 187 | 203 |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | (90) | (184) |
Tax loss carryforward | 96 | 156 |
Tax credit carryforward | 0 | 6 |
Investment in partnerships | 0 | 0 |
Other, net | 196 | 193 |
Deferred income tax liabilities (net) | (2,126) | (2,058) |
Unamortized investment tax credits | (8) | (8) |
Total deferred income tax liabilities (net) and unamortized investment tax credits | (2,134) | (2,066) |
Atlantic City Electric Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Plant basis differences | (645) | (607) |
Deferred Tax Liabilities, Other Finite-Lived Assets | 0 | 0 |
Derivatives and other financial instruments | 0 | 0 |
Deferred pension and postretirement obligation | (14) | (18) |
Deferred Tax Liabilities, Investments | 0 | 0 |
Deferred debt refinancing costs | (1) | (1) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | 83 | 86 |
Tax loss carryforward | 26 | 35 |
Tax credit carryforward | 0 | 0 |
Investment in partnerships | 0 | 0 |
Other, net | 19 | 16 |
Deferred income tax liabilities (net) | (532) | (489) |
Unamortized investment tax credits | (3) | (4) |
Total deferred income tax liabilities (net) and unamortized investment tax credits | (535) | (493) |
Delmarva Power & Light Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Plant basis differences | (743) | (717) |
Deferred Tax Liabilities, Other Finite-Lived Assets | 0 | 0 |
Derivatives and other financial instruments | 0 | 0 |
Deferred pension and postretirement obligation | (46) | (51) |
Deferred Tax Liabilities, Investments | 0 | 0 |
Deferred debt refinancing costs | (2) | (2) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | 96 | 88 |
Tax loss carryforward | 52 | 68 |
Tax credit carryforward | 0 | 0 |
Investment in partnerships | 0 | 0 |
Other, net | 17 | 14 |
Deferred income tax liabilities (net) | (626) | (600) |
Unamortized investment tax credits | (2) | (3) |
Total deferred income tax liabilities (net) and unamortized investment tax credits | (628) | (603) |
Potomac Electric Power Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Plant basis differences | (1,148) | (1,152) |
Deferred Tax Liabilities, Other Finite-Lived Assets | 0 | 0 |
Derivatives and other financial instruments | 0 | 0 |
Deferred pension and postretirement obligation | (78) | (78) |
Deferred Tax Liabilities, Investments | 0 | 0 |
Deferred debt refinancing costs | (4) | (4) |
Deferred Tax Liabilities, Regulatory Assets and Liabilities | 58 | 39 |
Tax loss carryforward | 12 | 40 |
Tax credit carryforward | 0 | 0 |
Investment in partnerships | 0 | 0 |
Other, net | 98 | 94 |
Deferred income tax liabilities (net) | (1,062) | (1,061) |
Unamortized investment tax credits | (2) | (2) |
Total deferred income tax liabilities (net) and unamortized investment tax credits | $ (1,064) | $ (1,063) |
Income Taxes - Schedule of Carr
Income Taxes - Schedule of Carryforwards and Corresponding Valuation Allowances (Details) $ in Millions | Dec. 31, 2018USD ($) | |
Internal Revenue Service (IRS) [Member] | General Business Tax Credit Carryforward [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Federal general business credits carryforwards | $ 811 | [1] |
Internal Revenue Service (IRS) [Member] | General Business Tax Credit Carryforward [Member] | Exelon Generation Co L L C [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Federal general business credits carryforwards | 816 | |
Internal Revenue Service (IRS) [Member] | General Business Tax Credit Carryforward [Member] | Commonwealth Edison Co [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Federal general business credits carryforwards | 0 | |
Internal Revenue Service (IRS) [Member] | General Business Tax Credit Carryforward [Member] | PECO Energy Co [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Federal general business credits carryforwards | 0 | |
Internal Revenue Service (IRS) [Member] | General Business Tax Credit Carryforward [Member] | Baltimore Gas and Electric Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Federal general business credits carryforwards | 0 | |
Internal Revenue Service (IRS) [Member] | General Business Tax Credit Carryforward [Member] | Pepco Holdings LLC [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Federal general business credits carryforwards | 0 | |
Internal Revenue Service (IRS) [Member] | General Business Tax Credit Carryforward [Member] | Potomac Electric Power Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Federal general business credits carryforwards | 0 | |
Internal Revenue Service (IRS) [Member] | General Business Tax Credit Carryforward [Member] | Delmarva Power & Light Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Federal general business credits carryforwards | 0 | |
Internal Revenue Service (IRS) [Member] | General Business Tax Credit Carryforward [Member] | Atlantic City Electric Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
Federal general business credits carryforwards | 0 | |
State and Local Jurisdiction [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
State net operating losses | 4,103 | [2] |
Deferred taxes on state tax attributes (net) | 272 | |
Valuation allowance on state tax attributes | 35 | |
State and Local Jurisdiction [Member] | Exelon Generation Co L L C [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
State net operating losses | 1,544 | [2] |
Deferred taxes on state tax attributes (net) | 104 | |
Valuation allowance on state tax attributes | 26 | |
State and Local Jurisdiction [Member] | Commonwealth Edison Co [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
State net operating losses | 0 | |
Deferred taxes on state tax attributes (net) | 0 | |
Valuation allowance on state tax attributes | 0 | |
State and Local Jurisdiction [Member] | PECO Energy Co [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
State net operating losses | 224 | [3] |
Deferred taxes on state tax attributes (net) | 18 | |
Valuation allowance on state tax attributes | 0 | |
State and Local Jurisdiction [Member] | Baltimore Gas and Electric Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
State net operating losses | 395 | [4] |
Deferred taxes on state tax attributes (net) | 26 | |
Valuation allowance on state tax attributes | 1 | |
State and Local Jurisdiction [Member] | Pepco Holdings LLC [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
State net operating losses | 1,492 | [5] |
Deferred taxes on state tax attributes (net) | 102 | |
Valuation allowance on state tax attributes | 6 | |
State and Local Jurisdiction [Member] | Potomac Electric Power Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
State net operating losses | 192 | [6] |
Deferred taxes on state tax attributes (net) | 12 | |
Valuation allowance on state tax attributes | 0 | |
State and Local Jurisdiction [Member] | Delmarva Power & Light Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
State net operating losses | 772 | [7] |
Deferred taxes on state tax attributes (net) | 52 | |
Valuation allowance on state tax attributes | 0 | |
State and Local Jurisdiction [Member] | Atlantic City Electric Company [Member] | ||
Operating Loss Carryforwards [Line Items] | ||
State net operating losses | 365 | [8] |
Deferred taxes on state tax attributes (net) | 26 | |
Valuation allowance on state tax attributes | $ 0 | |
[1] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246NUYzQjUwOTBEOUJENTE4OUJFODU2NDRDNjVGNkZEQzYM} | |
[2] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246MDkyRDA3MDExQ0UwNUM3Q0JGMTJENTVGQjRDRkUxMEUM} | |
[3] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246NTg5NzdDOUEwOTQ4NTk2NzlDM0NDM0NCREMxNDZGNEMM} | |
[4] | . | |
[5] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246RjE3NUQ0OEVCOEU4NTZBNjhDMkY3MzUwQUY0NTc3MDAM} | |
[6] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246NzBCNTFENTBCREJGNTIxMzhFRURCRkZFQzYxRDA1MDMM} | |
[7] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246OEMzNEQ1NEJCRDI5NTIxNUJCNTY4MkZEOEE3MEExOTcM} | |
[8] | . |
Income Taxes - Reconciliation o
Income Taxes - Reconciliation of Unrecognized Tax Benefits (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Income Taxes [Line Items] | |||
Unrecognized Tax Benefits, Increase Resulting from Acquisition | $ 22 | ||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||
Unrecognized tax benefits - beginning balance | $ 743 | $ 916 | 1,078 |
Increases based on tax positions related to current year | 108 | ||
Increases based on tax positions prior to current year | 15 | (332) | |
Decreases based on tax positions prior to current year | 30 | 28 | 88 |
Unrecognized Tax Benefits, Period Increase (Decrease) | (251) | (196) | (21) |
Decrease from settlements with taxing authorities | (53) | (5) | (27) |
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations | (7) | ||
Unrecognized tax benefits - ending balance | 477 | 743 | 916 |
Exelon Generation Co L L C [Member] | |||
Income Taxes [Line Items] | |||
Unrecognized Tax Benefits, Increase Resulting from Acquisition | 5 | ||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||
Unrecognized tax benefits - beginning balance | 468 | 490 | 534 |
Increases based on tax positions related to current year | 10 | ||
Increases based on tax positions prior to current year | 15 | (12) | |
Decreases based on tax positions prior to current year | 21 | 0 | 0 |
Unrecognized Tax Benefits, Period Increase (Decrease) | (36) | (17) | (20) |
Decrease from settlements with taxing authorities | (53) | (5) | (27) |
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations | (7) | ||
Unrecognized tax benefits - ending balance | 408 | 468 | 490 |
Commonwealth Edison Co [Member] | |||
Income Taxes [Line Items] | |||
Unrecognized Tax Benefits, Increase Resulting from Acquisition | 0 | ||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||
Unrecognized tax benefits - beginning balance | 2 | (12) | 142 |
Increases based on tax positions related to current year | 0 | ||
Increases based on tax positions prior to current year | 0 | (154) | |
Decreases based on tax positions prior to current year | 0 | 14 | 0 |
Unrecognized Tax Benefits, Period Increase (Decrease) | 0 | 0 | 0 |
Decrease from settlements with taxing authorities | 0 | 0 | 0 |
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations | 0 | ||
Unrecognized tax benefits - ending balance | 2 | 2 | (12) |
PECO Energy Co [Member] | |||
Income Taxes [Line Items] | |||
Unrecognized Tax Benefits, Increase Resulting from Acquisition | 0 | ||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||
Unrecognized tax benefits - beginning balance | 0 | 0 | 0 |
Increases based on tax positions related to current year | 0 | ||
Increases based on tax positions prior to current year | 0 | 0 | |
Decreases based on tax positions prior to current year | 0 | 0 | 0 |
Unrecognized Tax Benefits, Period Increase (Decrease) | 0 | 0 | 0 |
Decrease from settlements with taxing authorities | 0 | 0 | 0 |
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations | 0 | ||
Unrecognized tax benefits - ending balance | 0 | 0 | 0 |
Baltimore Gas and Electric Company [Member] | |||
Income Taxes [Line Items] | |||
Unrecognized Tax Benefits, Increase Resulting from Acquisition | 0 | ||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||
Unrecognized tax benefits - beginning balance | 120 | 120 | 120 |
Increases based on tax positions related to current year | 0 | ||
Increases based on tax positions prior to current year | 0 | 0 | |
Decreases based on tax positions prior to current year | 0 | 0 | 0 |
Unrecognized Tax Benefits, Period Increase (Decrease) | (120) | 0 | 0 |
Decrease from settlements with taxing authorities | 0 | 0 | 0 |
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations | 0 | ||
Unrecognized tax benefits - ending balance | 0 | 120 | 120 |
Potomac Electric Power Company [Member] | |||
Income Taxes [Line Items] | |||
Unrecognized Tax Benefits, Increase Resulting from Acquisition | 0 | ||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||
Unrecognized tax benefits - beginning balance | 59 | 80 | 8 |
Increases based on tax positions related to current year | 21 | ||
Increases based on tax positions prior to current year | 0 | 0 | |
Decreases based on tax positions prior to current year | 7 | 0 | 51 |
Unrecognized Tax Benefits, Period Increase (Decrease) | (66) | (21) | 0 |
Decrease from settlements with taxing authorities | 0 | 0 | 0 |
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations | 0 | ||
Unrecognized tax benefits - ending balance | 0 | 59 | 80 |
Delmarva Power & Light Company [Member] | |||
Income Taxes [Line Items] | |||
Unrecognized Tax Benefits, Increase Resulting from Acquisition | 0 | ||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||
Unrecognized tax benefits - beginning balance | 21 | 37 | 3 |
Increases based on tax positions related to current year | 16 | ||
Increases based on tax positions prior to current year | 0 | 0 | |
Decreases based on tax positions prior to current year | 1 | 0 | 18 |
Unrecognized Tax Benefits, Period Increase (Decrease) | (22) | (16) | 0 |
Decrease from settlements with taxing authorities | 0 | 0 | 0 |
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations | 0 | ||
Unrecognized tax benefits - ending balance | 0 | 21 | 37 |
Atlantic City Electric Company [Member] | |||
Income Taxes [Line Items] | |||
Unrecognized Tax Benefits, Increase Resulting from Acquisition | 0 | ||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||
Unrecognized tax benefits - beginning balance | 14 | 22 | 0 |
Increases based on tax positions related to current year | 22 | ||
Increases based on tax positions prior to current year | 0 | 0 | |
Decreases based on tax positions prior to current year | 0 | 14 | 0 |
Unrecognized Tax Benefits, Period Increase (Decrease) | 0 | (22) | 0 |
Decrease from settlements with taxing authorities | 0 | 0 | 0 |
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations | 0 | ||
Unrecognized tax benefits - ending balance | 14 | 14 | 22 |
Pepco Holdings LLC [Member] | |||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||
Unrecognized tax benefits - beginning balance | 125 | 172 | |
Increases based on tax positions prior to current year | 0 | ||
Decreases based on tax positions prior to current year | 8 | 14 | |
Unrecognized Tax Benefits, Period Increase (Decrease) | (88) | (61) | |
Decrease from settlements with taxing authorities | 0 | 0 | |
Unrecognized Tax Benefits, Reduction Resulting from Lapse of Applicable Statute of Limitations | 0 | ||
Unrecognized tax benefits - ending balance | $ 45 | 125 | 172 |
Pepco Holdings LLC [Member] | Predecessor [Member] | |||
Income Taxes [Line Items] | |||
Unrecognized Tax Benefits, Increase Resulting from Acquisition | (5) | ||
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | |||
Unrecognized tax benefits - beginning balance | $ 172 | 22 | |
Increases based on tax positions related to current year | 59 | ||
Increases based on tax positions prior to current year | 0 | ||
Decreases based on tax positions prior to current year | 96 | ||
Unrecognized Tax Benefits, Period Increase (Decrease) | 0 | ||
Decrease from settlements with taxing authorities | 0 | ||
Unrecognized tax benefits - ending balance | $ 172 |
Income Taxes - Summary of Inter
Income Taxes - Summary of Interest Receivable (Payable) (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 |
Income Taxes [Line Items] | ||
Net Interest Receivable Payable Related To Uncertain Tax Positions | $ 236 | $ 233 |
Unrecognized Tax Benefits, Income Tax Penalties Accrued | (17) | (17) |
Exelon Generation Co L L C [Member] | ||
Income Taxes [Line Items] | ||
Net Interest Receivable Payable Related To Uncertain Tax Positions | (2) | (3) |
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 |
Commonwealth Edison Co [Member] | ||
Income Taxes [Line Items] | ||
Net Interest Receivable Payable Related To Uncertain Tax Positions | 4 | 4 |
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 |
PECO Energy Co [Member] | ||
Income Taxes [Line Items] | ||
Net Interest Receivable Payable Related To Uncertain Tax Positions | 0 | 0 |
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 |
Baltimore Gas and Electric Company [Member] | ||
Income Taxes [Line Items] | ||
Net Interest Receivable Payable Related To Uncertain Tax Positions | 0 | 0 |
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 |
Pepco Holdings LLC [Member] | ||
Income Taxes [Line Items] | ||
Net Interest Receivable Payable Related To Uncertain Tax Positions | 1 | 2 |
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 |
Potomac Electric Power Company [Member] | ||
Income Taxes [Line Items] | ||
Net Interest Receivable Payable Related To Uncertain Tax Positions | 0 | 0 |
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 |
Delmarva Power & Light Company [Member] | ||
Income Taxes [Line Items] | ||
Net Interest Receivable Payable Related To Uncertain Tax Positions | 0 | 0 |
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 |
Atlantic City Electric Company [Member] | ||
Income Taxes [Line Items] | ||
Net Interest Receivable Payable Related To Uncertain Tax Positions | 0 | 0 |
Unrecognized Tax Benefits, Income Tax Penalties Accrued | $ 0 | $ 0 |
Income Taxes - Summary of Int_2
Income Taxes - Summary of Interest Expense (Income) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Income Taxes [Line Items] | |||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | $ 0 | $ (2) | $ 106 | ||
Net interest (income) expense recognized related to uncertain tax positions | (3) | 37 | 165 | ||
Exelon Generation Co L L C [Member] | |||||
Income Taxes [Line Items] | |||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||
Net interest (income) expense recognized related to uncertain tax positions | 0 | (1) | (13) | ||
Commonwealth Edison Co [Member] | |||||
Income Taxes [Line Items] | |||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 86 | ||
Net interest (income) expense recognized related to uncertain tax positions | 0 | 11 | 117 | ||
PECO Energy Co [Member] | |||||
Income Taxes [Line Items] | |||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||
Net interest (income) expense recognized related to uncertain tax positions | 0 | 0 | 0 | ||
Baltimore Gas and Electric Company [Member] | |||||
Income Taxes [Line Items] | |||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||
Net interest (income) expense recognized related to uncertain tax positions | 0 | 0 | 0 | ||
Pepco Holdings LLC [Member] | |||||
Income Taxes [Line Items] | |||||
Net interest (income) expense recognized related to uncertain tax positions | 0 | ||||
Pepco Holdings LLC [Member] | Successor [Member] | |||||
Income Taxes [Line Items] | |||||
Net interest (income) expense recognized related to uncertain tax positions | $ (2) | ||||
Pepco Holdings LLC [Member] | Predecessor [Member] | |||||
Income Taxes [Line Items] | |||||
Net interest (income) expense recognized related to uncertain tax positions | $ 0 | ||||
Potomac Electric Power Company [Member] | |||||
Income Taxes [Line Items] | |||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||
Net interest (income) expense recognized related to uncertain tax positions | 0 | 0 | 6 | ||
Delmarva Power & Light Company [Member] | |||||
Income Taxes [Line Items] | |||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||
Net interest (income) expense recognized related to uncertain tax positions | 0 | 0 | 0 | ||
Atlantic City Electric Company [Member] | |||||
Income Taxes [Line Items] | |||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||
Net interest (income) expense recognized related to uncertain tax positions | $ 0 | $ 0 | $ (1) |
Income Taxes - Narrative (Detai
Income Taxes - Narrative (Details) - USD ($) $ in Millions | Jul. 27, 2018 | Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Dec. 31, 2015 | Dec. 31, 1999 | ||
Income Taxes [Line Items] | |||||||||||||
Increase in Unrecognized Tax Benefits is Reasonably Possible | $ 71 | ||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21.00% | 35.00% | 35.00% | ||||||||||
Limitation on Deductible Interest Expense | 100.00% | ||||||||||||
Allowable Expensing For Cost Of Qualified Property | 30.00% | ||||||||||||
Unrecognized Tax Benefits | $ 477 | $ 916 | $ 477 | $ 743 | $ 916 | $ 1,078 | |||||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | (2) | 106 | ||||||||||
Unrecognized Tax Benefits, Increase Resulting from Settlements with Taxing Authorities | 9 | ||||||||||||
Decrease in Unrecognized Tax Benefits is Reasonably Possible | 90 | 241 | 241 | ||||||||||
Income taxes | 26 | 120 | (126) | 753 | |||||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | (251) | (196) | (21) | ||||||||||
Taxes accrued | 412 | 412 | 373 | ||||||||||
Unrecognized Tax Benefits, Income Tax Penalties Accrued | (17) | (17) | (17) | ||||||||||
Tax positions for which there is uncertainty about the timing of tax benefits | 83 | 7 | 83 | ||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | $ 20 | 463 | 633 | 463 | 523 | $ 633 | |||||||
Regulatory Liabilities | 10,203 | 10,203 | 10,388 | ||||||||||
Regulatory Assets | 9,459 | 9,459 | $ 9,288 | ||||||||||
Like kind exchange [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred gain on sale of property | $ 1,200 | ||||||||||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | $ 90 | ||||||||||||
Decrease in Unrecognized Tax Benefits is Reasonably Possible | $ 33 | ||||||||||||
Exelon Generation Co L L C [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21.00% | 35.00% | 35.00% | ||||||||||
Unrecognized Tax Benefits | 408 | 490 | $ 408 | $ 468 | $ 490 | 534 | |||||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||||||||||
Decrease in Unrecognized Tax Benefits is Reasonably Possible | 33 | 33 | |||||||||||
Income taxes | (108) | (1,376) | 282 | ||||||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | (36) | (17) | (20) | ||||||||||
Taxes accrued | 226 | 226 | 444 | ||||||||||
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 | 0 | ||||||||||
Tax positions for which there is uncertainty about the timing of tax benefits | 7 | 7 | |||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 408 | 483 | 408 | 461 | 483 | ||||||||
Allocation of federal tax benefit under tax sharing agreement | 155 | 94 | $ 155 | $ 102 | $ 94 | ||||||||
Commonwealth Edison Co [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21.00% | 35.00% | 35.00% | ||||||||||
Unrecognized Tax Benefits | 2 | (12) | $ 2 | $ 2 | $ (12) | 142 | |||||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 86 | ||||||||||
Income taxes | 168 | 417 | 301 | ||||||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | 0 | 0 | 0 | ||||||||||
Taxes accrued | 71 | 71 | 60 | ||||||||||
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 | 0 | ||||||||||
Tax positions for which there is uncertainty about the timing of tax benefits | (12) | $ (12) | |||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 2 | 2 | 2 | ||||||||||
Allocation of federal tax benefit under tax sharing agreement | 1 | 1 | |||||||||||
Regulatory Liabilities | 6,343 | $ 6,343 | 6,577 | ||||||||||
Regulatory Assets | $ 1,279 | ||||||||||||
Commonwealth Edison Co [Member] | Like kind exchange [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Decrease in Unrecognized Tax Benefits is Reasonably Possible | 2 | ||||||||||||
PECO Energy Co [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21.00% | 35.00% | 35.00% | ||||||||||
Unrecognized Tax Benefits | 0 | 0 | $ 0 | $ 0 | $ 0 | 0 | |||||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||||||||||
Income taxes | 6 | 104 | 149 | ||||||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | 0 | 0 | 0 | ||||||||||
Taxes accrued | 28 | 28 | 15 | ||||||||||
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 | 0 | ||||||||||
Allocation of federal tax benefit under tax sharing agreement | 48 | 18 | 48 | 16 | 18 | ||||||||
Regulatory Liabilities | 596 | $ 596 | 690 | ||||||||||
Regulatory Assets | 410 | ||||||||||||
Baltimore Gas and Electric Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Increase in Unrecognized Tax Benefits is Reasonably Possible | 120 | $ 120 | $ 120 | ||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21.00% | 35.00% | 35.00% | ||||||||||
Unrecognized Tax Benefits | 0 | 120 | $ 0 | $ 120 | $ 120 | 120 | |||||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||||||||||
Decrease in Unrecognized Tax Benefits is Reasonably Possible | 120 | 120 | |||||||||||
Income taxes | 74 | 218 | 174 | ||||||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | (120) | 0 | 0 | ||||||||||
Taxes accrued | 46 | 46 | 71 | ||||||||||
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 | 0 | ||||||||||
Allocation of federal tax benefit under tax sharing agreement | 26 | 8 | 26 | 10 | 8 | ||||||||
Regulatory Liabilities | 1,269 | $ 1,269 | 1,163 | ||||||||||
Regulatory Assets | 571 | ||||||||||||
Potomac Electric Power Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Increase in Unrecognized Tax Benefits is Reasonably Possible | 59 | $ 59 | $ 59 | ||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21.00% | 35.00% | 35.00% | ||||||||||
Unrecognized Tax Benefits | 0 | 80 | $ 0 | $ 59 | $ 80 | 8 | |||||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||||||||||
Decrease in Unrecognized Tax Benefits is Reasonably Possible | 66 | 66 | |||||||||||
Income taxes | 13 | 105 | 41 | ||||||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | (66) | (21) | 0 | ||||||||||
Taxes accrued | 58 | 58 | 68 | ||||||||||
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 | 0 | ||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 21 | 21 | |||||||||||
Regulatory Liabilities | 829 | $ 829 | 832 | ||||||||||
Regulatory Assets | 891 | ||||||||||||
Delmarva Power & Light Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Increase in Unrecognized Tax Benefits is Reasonably Possible | 21 | $ 21 | $ 21 | ||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21.00% | 35.00% | 35.00% | [1] | |||||||||
Unrecognized Tax Benefits | 0 | 37 | $ 0 | $ 21 | $ 37 | 3 | |||||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||||||||||
Decrease in Unrecognized Tax Benefits is Reasonably Possible | 22 | 22 | |||||||||||
Income taxes | 22 | 71 | 22 | ||||||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | (22) | (16) | 0 | ||||||||||
Taxes accrued | 4 | 4 | 4 | ||||||||||
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 | 0 | ||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 16 | $ 16 | |||||||||||
Regulatory Liabilities | 665 | $ 665 | 635 | ||||||||||
Regulatory Assets | 314 | ||||||||||||
Atlantic City Electric Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Increase in Unrecognized Tax Benefits is Reasonably Possible | $ 14 | ||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21.00% | 35.00% | 35.00% | [1] | |||||||||
Unrecognized Tax Benefits | 14 | 22 | $ 14 | $ 14 | $ 22 | 0 | |||||||
Unrecognized Tax Benefits, Income Tax Penalties Expense | 0 | 0 | 0 | ||||||||||
Income taxes | 12 | 26 | (4) | ||||||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | 0 | (22) | 0 | ||||||||||
Taxes accrued | 5 | 5 | 5 | ||||||||||
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 | 0 | ||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 22 | 22 | |||||||||||
Regulatory Liabilities | 420 | $ 420 | 422 | ||||||||||
Regulatory Assets | 430 | ||||||||||||
Pepco Holdings LLC [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Increase in Unrecognized Tax Benefits is Reasonably Possible | 80 | $ 94 | 80 | ||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 21.00% | 35.00% | |||||||||||
Unrecognized Tax Benefits | 45 | $ 172 | $ 45 | $ 125 | 172 | ||||||||
Income taxes | 35 | 217 | |||||||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | (88) | (61) | |||||||||||
Taxes accrued | 74 | 74 | 61 | ||||||||||
Unrecognized Tax Benefits, Income Tax Penalties Accrued | 0 | 0 | 0 | ||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 32 | ||||||||||||
Allocation of federal tax benefit under tax sharing agreement | 2 | 2 | 7 | ||||||||||
Regulatory Liabilities | 1,948 | 1,948 | 1,928 | ||||||||||
Regulatory Assets | 3,047 | ||||||||||||
Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | [1] | 35.00% | |||||||||||
Income taxes | $ 3 | ||||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 31 | 93 | 31 | 93 | |||||||||
Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 35.00% | ||||||||||||
Unrecognized Tax Benefits | 172 | 172 | $ 22 | ||||||||||
Decrease in Unrecognized Tax Benefits is Reasonably Possible | 88 | 88 | |||||||||||
Income taxes | $ 17 | ||||||||||||
Unrecognized Tax Benefits, Period Increase (Decrease) | 0 | ||||||||||||
Internal Revenue Service (IRS) [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | (98) | (471) | 600 | ||||||||||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | 146 | ||||||||||||
Internal Revenue Service (IRS) [Member] | Exelon Generation Co L L C [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | (347) | (2,005) | (254) | ||||||||||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | 19 | ||||||||||||
Internal Revenue Service (IRS) [Member] | Commonwealth Edison Co [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 145 | 523 | 379 | ||||||||||
Internal Revenue Service (IRS) [Member] | PECO Energy Co [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 10 | 28 | 72 | ||||||||||
Internal Revenue Service (IRS) [Member] | Baltimore Gas and Electric Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 47 | 101 | 88 | ||||||||||
Internal Revenue Service (IRS) [Member] | Potomac Electric Power Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | (21) | 114 | 136 | ||||||||||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | 21 | ||||||||||||
Internal Revenue Service (IRS) [Member] | Delmarva Power & Light Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 13 | 82 | 97 | ||||||||||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | 16 | ||||||||||||
Internal Revenue Service (IRS) [Member] | Atlantic City Electric Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 18 | 34 | 22 | ||||||||||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | 22 | ||||||||||||
Internal Revenue Service (IRS) [Member] | Pepco Holdings LLC [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 24 | 250 | |||||||||||
Internal Revenue Service (IRS) [Member] | Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 283 | ||||||||||||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | 59 | ||||||||||||
Internal Revenue Service (IRS) [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 10 | ||||||||||||
State and Local Jurisdiction [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 17 | 162 | 78 | ||||||||||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | 425 | 425 | |||||||||||
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | 411 | 411 | |||||||||||
Increase (Decrease) in Deferred Income Taxes | 50 | $ 16 | |||||||||||
Increase (Decrease) in Income Taxes | 50 | ||||||||||||
State and Local Jurisdiction [Member] | Exelon Generation Co L L C [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | (83) | 1 | (2) | ||||||||||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | 411 | 411 | |||||||||||
Increase (Decrease) in Deferred Income Taxes | 53 | 5 | |||||||||||
Increase (Decrease) in Income Taxes | 53 | ||||||||||||
State and Local Jurisdiction [Member] | Commonwealth Edison Co [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 117 | 136 | 63 | ||||||||||
State and Local Jurisdiction [Member] | PECO Energy Co [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | (16) | (9) | 5 | ||||||||||
State and Local Jurisdiction [Member] | Baltimore Gas and Electric Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 32 | 49 | 31 | ||||||||||
State and Local Jurisdiction [Member] | Potomac Electric Power Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 6 | 13 | 16 | ||||||||||
Increase (Decrease) in Deferred Income Taxes | 1 | 16 | |||||||||||
State and Local Jurisdiction [Member] | Delmarva Power & Light Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 12 | 13 | 12 | ||||||||||
Increase (Decrease) in Deferred Income Taxes | 2 | 1 | |||||||||||
State and Local Jurisdiction [Member] | Atlantic City Electric Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | 8 | 4 | $ 0 | ||||||||||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | 14 | 14 | |||||||||||
State and Local Jurisdiction [Member] | Pepco Holdings LLC [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Decrease in Unrecognized Tax Benefits is Reasonably Possible | 14 | 14 | |||||||||||
Deferred | 9 | $ 32 | |||||||||||
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | 14 | 14 | |||||||||||
Increase (Decrease) in Deferred Income Taxes | 4 | $ 17 | |||||||||||
Increase (Decrease) in Income Taxes | 3 | ||||||||||||
State and Local Jurisdiction [Member] | Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Decrease in Unrecognized Tax Benefits is Reasonably Possible | $ 21 | $ 21 | |||||||||||
Deferred | $ 13 | ||||||||||||
State and Local Jurisdiction [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Deferred | $ 7 | ||||||||||||
Net Regulatory Liabilities Associated With Marginal State Income Tax Rates [Member] | State and Local Jurisdiction [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Regulatory Liabilities | 1 | ||||||||||||
Net Regulatory Liabilities Associated With Marginal State Income Tax Rates [Member] | State and Local Jurisdiction [Member] | Delmarva Power & Light Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Regulatory Liabilities | 2 | ||||||||||||
Net Regulatory Liabilities Associated With Marginal State Income Tax Rates [Member] | State and Local Jurisdiction [Member] | Pepco Holdings LLC [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Regulatory Liabilities | 1 | ||||||||||||
Net Regulatory Assets Associated With Marginal State Income Tax Rates [Member] | State and Local Jurisdiction [Member] | Potomac Electric Power Company [Member] | |||||||||||||
Income Taxes [Line Items] | |||||||||||||
Regulatory Assets | $ 1 | ||||||||||||
[1] | DPL and ACE recognized a loss before income taxes for the year ended December 31, 2016, and PHI recognized a loss before income taxes for the period of March 24, 2016, through December 31, 2016. As a result, positive percentages represent an income tax benefit for the periods presented. |
Asset Retirement Obligations -
Asset Retirement Obligations - Nuclear Decommissioning Asset Retirement Obligation Rollforward (Details) - USD ($) | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||||||
Dec. 31, 2018 | Sep. 30, 2018 | Sep. 30, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | $ 489,000,000 | $ 468,000,000 | $ 446,000,000 | |||||
Asset Retirement Obligation, Revision of Estimate | 20,000,000 | 2,000,000 | |||||||
Atlantic City Electric Company [Member] | |||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 0 | 0 | 0 | |||||
Asset Retirement Obligation, Revision of Estimate | (1,000,000) | 2,000,000 | |||||||
Exelon Generation Co L L C [Member] | |||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 489,000,000 | 468,000,000 | 446,000,000 | |||||
Asset Retirement Obligation, Revision of Estimate | $ 203,000,000 | $ 84,000,000 | $ 138,000,000 | 0 | 0 | ||||
Asset Retirement Obligation, Period Increase (Decrease) | 180,000,000 | 34,000,000 | |||||||
Nuclear decommissioning | |||||||||
Asset Retirement Obligation Roll Forward Analysis [Line Items] | |||||||||
Proceeds from Customers | 144,000,000 | 77,000,000 | |||||||
Nuclear decommissioning | Exelon Generation Co L L C [Member] | |||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||
ARO beginning balance | 8,734,000,000 | 9,662,000,000 | [2] | 8,734,000,000 | |||||
Asset Retirement Obligation, Accretion Expense | 478,000,000 | 458,000,000 | |||||||
Asset Retirement Obligation, Revision of Estimate | $ 772,000,000 | 444,000,000 | |||||||
Asset Retirement Obligation, Period Increase (Decrease) | (77,000,000) | 34,000,000 | |||||||
ARO ending balance | 10,005,000,000 | 10,005,000,000 | 9,662,000,000 | [2] | 8,734,000,000 | ||||
Asset Retirement Obligation, Current | 22,000,000 | 22,000,000 | 13,000,000 | ||||||
Asset Retirement Obligation, Liabilities Incurred | (58,000,000) | 8,000,000 | |||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | |||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||
Asset Retirement Obligation, Period Increase (Decrease) | (3,000,000) | ||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Atlantic City Electric Company [Member] | |||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||
ARO beginning balance | 3,000,000 | 3,000,000 | 3,000,000 | ||||||
Asset Retirement Obligation, Accretion Expense | 0 | 0 | |||||||
Asset Retirement Obligation, Revision of Estimate | 1,000,000 | 0 | |||||||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | 0 | |||||||
ARO ending balance | 4,000,000 | 4,000,000 | 3,000,000 | 3,000,000 | |||||
Asset Retirement Obligation, Liabilities Incurred | [3] | 0 | |||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Exelon Generation Co L L C [Member] | |||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||
ARO beginning balance | $ 199,000,000 | 197,000,000 | 199,000,000 | ||||||
Asset Retirement Obligation, Accretion Expense | 10,000,000 | 10,000,000 | |||||||
Asset Retirement Obligation, Revision of Estimate | 35,000,000 | (1,000,000) | |||||||
Asset Retirement Obligation, Period Increase (Decrease) | (3,000,000) | (7,000,000) | |||||||
ARO ending balance | $ 238,000,000 | $ 238,000,000 | 197,000,000 | $ 199,000,000 | |||||
Asset Retirement Obligation, Liabilities Incurred | [3] | $ 1,000,000 | |||||||
[1] | Included in Operating and maintenance expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. | ||||||||
[2] | Includes $22 million and $13 million as the current portion of the ARO at December 31, 2018 and 2017, respectively, which is included in Other current liabilities in Exelon’s and Generation’s Consolidated Balance Sheets. | ||||||||
[3] | . |
Asset Retirement Obligations _2
Asset Retirement Obligations - Narrative (Details) - USD ($) | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||||||
Dec. 31, 2018 | Sep. 30, 2018 | Mar. 31, 2018 | Sep. 30, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Jun. 30, 2018 | ||
Asset Retirement Obligations [Line Items] | |||||||||
Asset retirement obligations, noncurrent | $ 9,679,000,000 | $ 9,679,000,000 | $ 10,029,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | $ 20,000,000 | $ 2,000,000 | |||||||
Percent of additional decommissioning shortfall with recourse | 50.00% | 50.00% | |||||||
Nuclear decommissioning trust funds | $ 11,661,000,000 | $ 11,661,000,000 | 13,272,000,000 | ||||||
Spent Nuclear Fuel Obligation, Noncurrent | 1,171,000,000 | 1,171,000,000 | 1,147,000,000 | ||||||
Line of credit facility, maximum borrowing capacity | [1] | 9,704,000,000 | 9,704,000,000 | ||||||
Exelon Generation Co L L C [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Asset Retirement Obligation, Period Increase (Decrease) | $ 180,000,000 | 34,000,000 | |||||||
Recovery Stranded Costs | $ 4,000,000 | 24,000,000 | |||||||
Asset retirement obligations, noncurrent | 9,450,000,000 | 9,450,000,000 | 9,844,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | 203,000,000 | $ 84,000,000 | $ 138,000,000 | 0 | 0 | ||||
Shortfall of decommissioning funds with recourse | 0 | 0 | 50,000,000 | ||||||
Nuclear decommissioning trust funds | 11,661,000,000 | 11,661,000,000 | 13,272,000,000 | ||||||
Spent Nuclear Fuel Obligation, Noncurrent | 1,171,000,000 | 1,171,000,000 | 1,147,000,000 | ||||||
ZionSolutions rent payable | 1 | ||||||||
Line of credit facility, maximum borrowing capacity | $ 200,000,000 | $ 200,000,000 | $ 45,000,000 | ||||||
Annual average accretion of the ARO | 4.863% | ||||||||
Number of years used in present value measurement | 30 years | ||||||||
Historical five-year annual average after-tax return on NDT funds | 5.00% | ||||||||
Exelon Generation Co L L C [Member] | Minimum [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Investment Interest Rate | 1000.00% | ||||||||
Estimated annual after tax return on nuclear decommissioning funds | 5.00% | 5.00% | |||||||
Exelon Generation Co L L C [Member] | Maximum [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Investment Interest Rate | 7000.00% | ||||||||
Estimated annual after tax return on nuclear decommissioning funds | 6.20% | 6.20% | |||||||
Nuclear Plant [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Asset Retirement Obligation, Revision of Estimate | $ 890,000,000 | ||||||||
Nuclear Plant [Member] | Exelon Generation Co L L C [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Asset Retirement Obligation, Period Increase (Decrease) | $ 116,000,000 | $ 178,000,000 | |||||||
Asset Retirement Obligation, Revision of Estimate | 122,000,000 | ||||||||
Decommissioning Liability, Noncurrent | 120,000,000 | 120,000,000 | |||||||
Nuclear decommissioning | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Proceeds from Customers | 144,000,000 | 77,000,000 | |||||||
Nuclear decommissioning | Exelon Generation Co L L C [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Asset Retirement Obligation, Period Increase (Decrease) | (77,000,000) | 34,000,000 | |||||||
Asset Retirement Obligation, Revision of Estimate | $ 772,000,000 | 444,000,000 | |||||||
Zion Station [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Decommissioning Liability, Noncurrent | 0 | 0 | |||||||
Zion Station [Member] | Exelon Generation Co L L C [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Decommissioning Liability, Noncurrent | 0 | 0 | |||||||
Assets, Total [Member] | |||||||||
Asset Retirement Obligations [Line Items] | |||||||||
Nuclear decommissioning trust funds | $ 12,695,000,000 | $ 12,695,000,000 | $ 13,349,000,000 | ||||||
[1] | Excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million, $33 million, $34 million, $5 million, $5 million, $5 million and $5 million, respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. As of December 31, 2018, letters of credit issued under these facilities totaled $5 million and $2 million for Generation and BGE, respectively. |
Asset Retirement Obligations _3
Asset Retirement Obligations - Unrealized Gain on NDT Funds (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Asset Retirement Obligations [Line Items] | |||
Decommissioning Fund Investments | $ 11,661 | $ 13,272 | |
Exelon Generation Co L L C [Member] | |||
Asset Retirement Obligations [Line Items] | |||
Decommissioning Fund Investments | 11,661 | 13,272 | |
Collateral Pledged [Member] | Unregulated Operation [Member] | Exelon Generation Co L L C [Member] | |||
Asset Retirement Obligations [Line Items] | |||
Unrealized Gain (Loss) on Investments | (483) | 521 | $ 194 |
Collateral Pledged [Member] | Regulated Operation [Member] | Exelon Generation Co L L C [Member] | |||
Asset Retirement Obligations [Line Items] | |||
Unrealized Gain (Loss) on Investments | (715) | 455 | $ 216 |
Assets, Total [Member] | |||
Asset Retirement Obligations [Line Items] | |||
Decommissioning Fund Investments | $ 12,695 | $ 13,349 |
Asset Retirement Obligations _4
Asset Retirement Obligations - Pledged Assets and Payables to ZionSolutions (Details) - USD ($) | Dec. 31, 2018 | Jun. 30, 2018 | Dec. 31, 2017 | |
Asset Retirement Obligations [Line Items] | ||||
Line of credit facility, maximum borrowing capacity | [1] | $ 9,704,000,000 | ||
Asset retirement obligations, noncurrent | 9,679,000,000 | $ 10,029,000,000 | ||
Exelon Generation Co L L C [Member] | ||||
Asset Retirement Obligations [Line Items] | ||||
Line of credit facility, maximum borrowing capacity | 200,000,000 | $ 45,000,000 | ||
Asset retirement obligations, noncurrent | 9,450,000,000 | 9,844,000,000 | ||
Exelon Generation Co L L C [Member] | Nuclear Decommissioning Asset Retirement Obligation [Member] | ||||
Asset Retirement Obligations [Line Items] | ||||
Held-to-maturity Securities Pledged as Collateral | [2] | 9,000,000 | 39,000,000 | |
Accounts Payable, Interest-bearing, Noncurrent | 9,000,000 | 37,000,000 | ||
Accounts Payable, Interest-bearing, Current | $ 965 | $ 942,000,000 | ||
[1] | Excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million, $33 million, $34 million, $5 million, $5 million, $5 million and $5 million, respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. As of December 31, 2018, letters of credit issued under these facilities totaled $5 million and $2 million for Generation and BGE, respectively. | |||
[2] | (a)Included in Other current liabilities within Exelon's and Generation's Consolidated Balance Sheets. Excludes a liability recorded within Exelon’s and Generation’s Consolidated Balance Sheets related to the tax obligation on the unrealized gains and losses associated with the Zion Station NDT funds. The NDT funds will be utilized to satisfy the tax obligations as gains and losses are realized. |
Asset Retirement Obligations _5
Asset Retirement Obligations - Non-Nuclear Asset Retirement Obligations Rollforward (Details) - USD ($) | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||||||||
Dec. 31, 2018 | Sep. 30, 2018 | Mar. 23, 2016 | Sep. 30, 2017 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Revision of Estimate | $ 20,000,000 | $ 2,000,000 | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 489,000,000 | $ 468,000,000 | 446,000,000 | |||||||
Asset Retirement Obligation, Revision of Estimate | 20,000,000 | 2,000,000 | |||||||||
Exelon Generation Co L L C [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Revision of Estimate | $ 203,000,000 | $ 84,000,000 | $ 138,000,000 | 0 | 0 | ||||||
Asset Retirement Obligation, Accretion Expense | [1] | 489,000,000 | 468,000,000 | 446,000,000 | |||||||
Asset Retirement Obligation, Period Increase (Decrease) | 180,000,000 | 34,000,000 | |||||||||
Asset Retirement Obligation, Revision of Estimate | 203,000,000 | 84,000,000 | 138,000,000 | 0 | 0 | ||||||
PECO Energy Co [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 0 | 0 | 0 | |||||||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | |||||||||
Baltimore Gas and Electric Company [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 0 | 0 | 0 | |||||||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | |||||||||
Pepco Holdings LLC [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 0 | 0 | ||||||||
Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Revision of Estimate | $ 2,000,000 | 20,000,000 | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 0 | |||||||||
Asset Retirement Obligation, Revision of Estimate | 2,000,000 | 20,000,000 | |||||||||
Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Revision of Estimate | $ 0 | ||||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 0 | |||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | ||||||||||
Potomac Electric Power Company [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 22,000,000 | 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 0 | 0 | 0 | |||||||
Asset Retirement Obligation, Revision of Estimate | 22,000,000 | 0 | |||||||||
Delmarva Power & Light Company [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Revision of Estimate | (1,000,000) | 1,000,000 | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 0 | 0 | 0 | |||||||
Asset Retirement Obligation, Revision of Estimate | (1,000,000) | 1,000,000 | |||||||||
Atlantic City Electric Company [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Revision of Estimate | (1,000,000) | 2,000,000 | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 0 | 0 | 0 | |||||||
Asset Retirement Obligation, Revision of Estimate | (1,000,000) | 2,000,000 | |||||||||
Commonwealth Edison Co [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | [1] | 0 | 0 | 0 | |||||||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | |||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Period Increase (Decrease) | (3,000,000) | ||||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Exelon Generation Co L L C [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
ARO beginning balance | 199,000,000 | 197,000,000 | 199,000,000 | ||||||||
Asset Retirement Obligation, Revision of Estimate | 35,000,000 | (1,000,000) | |||||||||
Development projects | [2] | 1,000,000 | |||||||||
Asset Retirement Obligation, Accretion Expense | 10,000,000 | 10,000,000 | |||||||||
Asset Retirement Obligation, Period Increase (Decrease) | (3,000,000) | (7,000,000) | |||||||||
Payments | (1,000,000) | (5,000,000) | |||||||||
ARO ending balance | 238,000,000 | 199,000,000 | 238,000,000 | 197,000,000 | 199,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | 35,000,000 | (1,000,000) | |||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | PECO Energy Co [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
ARO beginning balance | 28,000,000 | 27,000,000 | 28,000,000 | ||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | (1,000,000) | |||||||||
Development projects | [2] | 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | [3] | 1,000,000 | 1,000,000 | ||||||||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | 0 | |||||||||
Payments | 0 | (1,000,000) | |||||||||
ARO ending balance | 28,000,000 | 28,000,000 | 28,000,000 | 27,000,000 | 28,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | 0 | (1,000,000) | |||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Baltimore Gas and Electric Company [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
ARO beginning balance | 24,000,000 | 24,000,000 | 24,000,000 | ||||||||
Asset Retirement Obligation, Revision of Estimate | 2,000,000 | 2,000,000 | |||||||||
Development projects | [2] | 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | [3] | 1,000,000 | 0 | ||||||||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | 0 | |||||||||
Payments | (2,000,000) | (2,000,000) | |||||||||
ARO ending balance | 25,000,000 | 24,000,000 | 25,000,000 | 24,000,000 | 24,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | 2,000,000 | 2,000,000 | |||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Pepco Holdings LLC [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
ARO beginning balance | 14,000,000 | 16,000,000 | 14,000,000 | ||||||||
Asset Retirement Obligation, Revision of Estimate | 36,000,000 | 2,000,000 | |||||||||
Development projects | [2] | $ 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | 0 | 0 | |||||||||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | ||||||||||
Payments | 0 | 0 | |||||||||
ARO ending balance | 52,000,000 | 14,000,000 | 52,000,000 | 16,000,000 | 14,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | 36,000,000 | 2,000,000 | |||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | ||||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Potomac Electric Power Company [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
ARO beginning balance | 2,000,000 | 3,000,000 | 2,000,000 | ||||||||
Asset Retirement Obligation, Revision of Estimate | 22,000,000 | 34,000,000 | 1,000,000 | ||||||||
Development projects | [2] | 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | 0 | 0 | |||||||||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | 0 | |||||||||
Payments | 0 | 0 | |||||||||
ARO ending balance | 37,000,000 | 2,000,000 | 37,000,000 | 3,000,000 | 2,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | 22,000,000 | 34,000,000 | 1,000,000 | ||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Delmarva Power & Light Company [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
ARO beginning balance | 9,000,000 | 10,000,000 | 9,000,000 | ||||||||
Asset Retirement Obligation, Revision of Estimate | 1,000,000 | 1,000,000 | |||||||||
Development projects | [2] | 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | 0 | 0 | |||||||||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | 0 | |||||||||
Payments | 0 | 0 | |||||||||
ARO ending balance | 11,000,000 | 9,000,000 | 11,000,000 | 10,000,000 | 9,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | 1,000,000 | 1,000,000 | |||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Atlantic City Electric Company [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
ARO beginning balance | 3,000,000 | 3,000,000 | 3,000,000 | ||||||||
Asset Retirement Obligation, Revision of Estimate | 1,000,000 | 0 | |||||||||
Development projects | [2] | 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | 0 | 0 | |||||||||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | 0 | |||||||||
Payments | 0 | 0 | |||||||||
ARO ending balance | 4,000,000 | 3,000,000 | 4,000,000 | 3,000,000 | 3,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | 1,000,000 | 0 | |||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Exelon Enterprise [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
Asset Retirement Obligation, Period Increase (Decrease) | (7,000,000) | ||||||||||
Nonnuclear Decommissioning Asset Retirement Obligation [Member] | Commonwealth Edison Co [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
ARO beginning balance | 121,000,000 | 113,000,000 | 121,000,000 | ||||||||
Asset Retirement Obligation, Revision of Estimate | 7,000,000 | (13,000,000) | |||||||||
Development projects | [2] | 0 | |||||||||
Asset Retirement Obligation, Accretion Expense | [3] | 4,000,000 | 7,000,000 | ||||||||
Asset Retirement Obligation, Period Increase (Decrease) | 0 | 0 | |||||||||
Payments | (3,000,000) | (2,000,000) | |||||||||
ARO ending balance | 121,000,000 | 121,000,000 | 121,000,000 | 113,000,000 | 121,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | 7,000,000 | (13,000,000) | |||||||||
Nuclear decommissioning | Exelon Generation Co L L C [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
ARO beginning balance | 8,734,000,000 | 9,662,000,000 | [4] | 8,734,000,000 | |||||||
Asset Retirement Obligation, Revision of Estimate | 772,000,000 | 444,000,000 | |||||||||
Development projects | (58,000,000) | 8,000,000 | |||||||||
Asset Retirement Obligation, Accretion Expense | 478,000,000 | 458,000,000 | |||||||||
Asset Retirement Obligation, Period Increase (Decrease) | (77,000,000) | 34,000,000 | |||||||||
ARO ending balance | 10,005,000,000 | 8,734,000,000 | 10,005,000,000 | 9,662,000,000 | [4] | 8,734,000,000 | |||||
Asset Retirement Obligation, Revision of Estimate | $ 772,000,000 | 444,000,000 | |||||||||
Asset Retirement Obligation, Current | 22,000,000 | 22,000,000 | 13,000,000 | ||||||||
Nuclear decommissioning | Exelon Enterprise [Member] | |||||||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | |||||||||||
ARO beginning balance | $ 393,000,000 | 384,000,000 | 393,000,000 | ||||||||
Asset Retirement Obligation, Revision of Estimate | 80,000,000 | (11,000,000) | |||||||||
Development projects | [2] | 1,000,000 | |||||||||
Asset Retirement Obligation, Accretion Expense | 16,000,000 | 18,000,000 | |||||||||
Payments | (6,000,000) | (10,000,000) | |||||||||
ARO ending balance | $ 471,000,000 | $ 393,000,000 | 471,000,000 | 384,000,000 | $ 393,000,000 | ||||||
Asset Retirement Obligation, Revision of Estimate | $ 80,000,000 | $ (11,000,000) | |||||||||
[1] | Included in Operating and maintenance expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. | ||||||||||
[2] | . | ||||||||||
[3] | (b)In 2018, Pepco recorded an increase of $22 million in Operating and maintenance expense primarily related to asbestos identified at its Buzzard Point property as part of an annual ARO study. Buzzard Point is a waterfront property in the District of Columbia occupied by an active substation and former Pepco operated steam plant building, which Pepco retired and closed in 1981. | ||||||||||
[4] | Includes $22 million and $13 million as the current portion of the ARO at December 31, 2018 and 2017, respectively, which is included in Other current liabilities in Exelon’s and Generation’s Consolidated Balance Sheets. |
Retirement Benefits Retirement
Retirement Benefits Retirement Benefits- Narrative (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||||
Mar. 31, 2018 | Dec. 31, 2019 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Increase (Decrease) in Obligation, Pension Benefits | $ 23 | ||||||||
Benefit obligation increase (decrease) reflecting actual census data | (14) | ||||||||
Accumulated Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), after Tax | 18 | ||||||||
Regulatory asset increase (decrease) due to updated valuation adjustment | 61 | ||||||||
Defined benefit plan, amounts recognized In regulatory liabilities, before tax | $ 1 | ||||||||
Defined Contribution Plan, Employer Discretionary Contribution Amount | [1] | $ 179 | $ 128 | $ 164 | |||||
Fitzpatrick [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Increase (Decrease) in Obligation, Pension Benefits | 16 | ||||||||
Benefit obligation increase (decrease) reflecting actual census data | $ (17) | ||||||||
Projected Benefit Obligation In Excess Of Plan Assets [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Defined Benefit Plan, Funded Percentage | 81.00% | 80.00% | |||||||
Accumulated Benefit Obligation In Excess Of Plan Assets [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Defined Benefit Plan, Funded Percentage | 85.00% | 88.00% | |||||||
Pension Plan, Defined Benefit [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Regulatory asset increase (decrease) due to updated valuation adjustment | $ (6) | $ (423) | [2] | $ 959 | |||||
Expected return on plan assets | 7.00% | 7.00% | 7.00% | ||||||
Discount rate | [4] | 3.62% | [3],[5] | 4.04% | [6],[7] | 4.29% | [8] | ||
Defined Contribution Plan, Employer Discretionary Contribution Amount | $ 300 | ||||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Regulatory asset increase (decrease) due to updated valuation adjustment | $ (57) | $ 125 | [2] | $ 95 | |||||
Expected return on plan assets | 6.60% | 6.58% | 6.71% | ||||||
Discount rate | [4] | 3.61% | [3],[5] | 4.04% | [6],[7] | 4.29% | [7],[8] | ||
Change in Assumptions for Defined Benefit Plans [Member] | Pension Plan, Defined Benefit [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Expected return on plan assets | 7.00% | ||||||||
Discount rate | 3.62% | ||||||||
Change in Assumptions for Defined Benefit Plans [Member] | Other Postretirement Benefit Plan, Defined Benefit [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Expected return on plan assets | 6.60% | ||||||||
Discount rate | 3.61% | ||||||||
Assets [Member] | Pension Plan, Defined Benefit [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Discount rate | (4.86%) | ||||||||
Assets [Member] | Other Postretirement Benefit Plan, Defined Benefit [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Discount rate | (4.66%) | ||||||||
Subsequent Event [Member] | Pension Plan, Defined Benefit [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Expected return on plan assets | 7.00% | ||||||||
Subsequent Event [Member] | Other Postretirement Benefit Plan, Defined Benefit [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Expected return on plan assets | 6.67% | ||||||||
[1] | Includes $13 million related to CENG for the year ended December 31, 2016 | ||||||||
[2] | 2016 amounts include PHI for the period of March 24, 2016 through December 31, 2016. | ||||||||
[3] | (a)The discount rates above represent the blended rates used to establish the majority of Exelon’s pension and other postretirement benefits costs for the year ended December 31, 2018. Certain benefit plans used individual rates ranging from 3.49%-3.65% and 3.57%-3.68% for pension and other postretirement plans, respectively. | ||||||||
[4] | (d)Not applicable to pension and other postretirement benefit plans that do not have plan assets. | ||||||||
[5] | (e)3.25% through 2019 and 3.75% thereafter. | ||||||||
[6] | (b)The discount rates above represent the blended rates used to establish the majority of Exelon's pension and other postretirement benefits costs for the year ended December 31, 2017. Certain benefit plans used individual rates ranging from 3.66%-4.11% and 4.00%-4.17% for pension and other postretirement plans, respectively. | ||||||||
[7] | (f)The legacy Exelon, CEG and CENG pension and other postretirement plans used a rate of compensation increase of 3.25% through 2019 and 3.75% thereafter, while the legacy PHI pension and other postretirement plans used a weighted-average rate of compensation increase of 5% for all periods. | ||||||||
[8] | (c)The discount rates above represent the blended rates used to establish the majority of Exelon’s pension and other postretirement benefits costs for the year ended December 31, 2016. Certain benefit plans used the individual rates ranging from 3.68%-4.14% and 4.32%-4.43% for pension and other postretirement plans, respectively. |
Retirement Benefits Retiremen_2
Retirement Benefits Retirement Benefits - Summary of Changes in Benefit Obligations and Plan Assets (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||
Mar. 23, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||||||
Employer contributions | $ 13 | ||||||
Pension Plan, Defined Benefit [Member] | |||||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||||||
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Remeasurement due to Settlement | $ 48 | (34) | |||||
Net benefit obligation at beginning of year | 22,337 | 21,060 | |||||
Service cost | 405 | [1] | 387 | [2] | $ 354 | ||
Interest cost | 802 | [1] | 842 | [2] | 830 | ||
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant | 0 | 0 | |||||
Actuarial (gain) loss(a) | [3] | (1,561) | 1,182 | ||||
Plan amendments | (4) | 9 | |||||
Acquisitions(b) | [4] | 0 | 16 | ||||
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (1,239) | (1,125) | |||||
Net benefit obligation at end of year | 20,692 | 22,337 | 21,060 | ||||
Fair value of net plan assets at beginning of year | 18,573 | 16,791 | |||||
Actual return on plan assets | (945) | 2,600 | |||||
Employer contributions | 337 | 341 | |||||
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 0 | 0 | |||||
Defined Benefit Plan, Plan Assets, Benefits Paid | (1,239) | (1,125) | |||||
Defined Benefit Plan, Fair Value of Plan Assets | 16,678 | 18,573 | 16,791 | ||||
Pension Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||||||
Service cost | $ 12 | ||||||
Interest cost | 26 | ||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | |||||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||||||
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Remeasurement due to Settlement | 4 | 0 | |||||
Net benefit obligation at beginning of year | 4,856 | 4,457 | |||||
Service cost | 112 | [1] | 106 | [2] | 107 | ||
Interest cost | 175 | [1] | 182 | [2] | 185 | ||
Defined Benefit Plan, Benefit Obligation, Contributions by Plan Participant | 45 | 53 | |||||
Actuarial (gain) loss(a) | [3] | (540) | 350 | ||||
Plan amendments | 0 | 0 | |||||
Acquisitions(b) | [4] | 0 | 17 | ||||
Defined Benefit Plan, Benefit Obligation, Benefits Paid | (275) | (309) | |||||
Net benefit obligation at end of year | 4,369 | 4,856 | 4,457 | ||||
Fair value of net plan assets at beginning of year | 2,732 | 2,578 | |||||
Actual return on plan assets | (136) | 346 | |||||
Employer contributions | 46 | 64 | |||||
Defined Benefit Plan, Plan Assets, Contributions by Plan Participant | 45 | 53 | |||||
Defined Benefit Plan, Plan Assets, Benefits Paid | (275) | (309) | |||||
Defined Benefit Plan, Fair Value of Plan Assets | $ 2,408 | $ 2,732 | $ 2,578 | ||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||
Defined Benefit Plan, Change in Benefit Obligation [Roll Forward] | |||||||
Service cost | 1 | ||||||
Interest cost | $ 6 | ||||||
[1] | FitzPatrick net benefit costs are included for the period after acquisition. | ||||||
[2] | PHI net periodic benefit costs for the period prior to the merger are not included in the table above. | ||||||
[3] | (a)The pension actuarial gain in 2018 primarily reflects an increase in the discount rate. The OPEB actuarial gain in 2018 primarily reflects an increase in the discount rate and favorable health care claims experience. The pension and OPEB actuarial losses in 2017 primarily reflect a decrease in the discount rate. | ||||||
[4] | (b)Exelon recorded pension and OPEB obligations associated with its acquisition of Fitzpatrick on March 31, 2017. |
Retirement Benefits Retiremen_3
Retirement Benefits Retirement Benefits - Balance Sheet locations of Benefit Obligations and Plan Assets (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 |
Pension Plan, Defined Benefit [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Other current liabilities | $ 26 | $ 28 |
Pension obligations | 3,988 | 3,736 |
Non-pension postretirement benefit obligations | 0 | 0 |
Unfunded status (net benefit obligation less plan assets) | 4,014 | 3,764 |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Other current liabilities | 33 | 31 |
Pension obligations | 0 | 0 |
Non-pension postretirement benefit obligations | 1,928 | 2,093 |
Unfunded status (net benefit obligation less plan assets) | $ 1,961 | $ 2,124 |
Retirement Benefits Reitrement
Retirement Benefits Reitrement Benefits- Projected Benefit Obligations and Accumulated Benefit Obligations in Excess of Plan Assets (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 |
Projected Benefit Obligation In Excess Of Plan Assets [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Projected benefit obligation | $ 20,692 | $ 22,337 |
Fair value of net plan assets | 16,678 | 18,573 |
Accumulated Benefit Obligation In Excess Of Plan Assets [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Accumulated benefit obligation | $ 19,656 | $ 21,153 |
Retirement Benefits Retiremen_4
Retirement Benefits Retirement Benefits - Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||
Mar. 23, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Net periodic benefit cost | $ 47 | $ 109 | $ 116 | ||||
Pension Plan, Defined Benefit [Member] | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | [1] | (1,561) | 1,182 | ||||
Service cost | 405 | [2] | 387 | [3] | 354 | ||
Interest cost | 802 | [2] | 842 | [3] | 830 | ||
Expected return on assets | (1,252) | [2] | (1,196) | [3] | (1,141) | ||
Prior service cost (credit) | 2 | [2] | 1 | [3] | 14 | ||
Actuarial loss | 629 | [2] | 607 | [3] | 554 | ||
Settlement and other charges(c) | 3 | [2],[4] | 3 | [3],[4] | 2 | ||
Net periodic benefit cost | 589 | [2] | 644 | [3] | 613 | ||
Pension Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Service cost | $ 12 | ||||||
Interest cost | 26 | ||||||
Expected return on assets | 30 | ||||||
Prior service cost (credit) | 0 | ||||||
Actuarial loss | (14) | ||||||
Net periodic benefit cost | 22 | ||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Defined Benefit Plan, Benefit Obligation, Actuarial Gain (Loss) | [1] | (540) | 350 | ||||
Service cost | 112 | [2] | 106 | [3] | 107 | ||
Interest cost | 175 | [2] | 182 | [3] | 185 | ||
Expected return on assets | (173) | [2] | (162) | [3] | (162) | ||
Prior service cost (credit) | (186) | [2] | (188) | [3] | (185) | ||
Actuarial loss | 66 | [2] | 61 | [3] | 63 | ||
Settlement and other charges(c) | 1 | [2],[4] | 0 | [3],[4] | 0 | ||
Net periodic benefit cost | $ (5) | [2] | $ (1) | [3] | $ 8 | ||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Service cost | 1 | ||||||
Interest cost | 6 | ||||||
Expected return on assets | 5 | ||||||
Prior service cost (credit) | (3) | ||||||
Actuarial loss | (2) | ||||||
Net periodic benefit cost | $ 1 | ||||||
[1] | (a)The pension actuarial gain in 2018 primarily reflects an increase in the discount rate. The OPEB actuarial gain in 2018 primarily reflects an increase in the discount rate and favorable health care claims experience. The pension and OPEB actuarial losses in 2017 primarily reflect a decrease in the discount rate. | ||||||
[2] | FitzPatrick net benefit costs are included for the period after acquisition. | ||||||
[3] | PHI net periodic benefit costs for the period prior to the merger are not included in the table above. | ||||||
[4] | 2016 amount includes an additional termination benefit for PHI. |
Retirement Benefits Retiremen_5
Retirement Benefits Retirement Benefits - Components of Accumulated Other Comprehensive Income and Regulatory Assets (Liabilities) related to Retirement Plans (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||
Mar. 31, 2018 | Mar. 23, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Defined benefit plan, amounts recognized in regulatory assets, before tax | $ 61 | ||||||
Pension Plan, Defined Benefit [Member] | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Current year actuarial (gain) loss | $ 635 | $ (222) | [1] | $ 644 | |||
Amortization of actuarial loss | (629) | (607) | [1] | (554) | |||
Current year prior service cost (credit) | (4) | 9 | [1] | (60) | |||
Amortization of prior service (cost) credit | (2) | (1) | [1] | (14) | |||
Settlements | 3 | (3) | [1] | 0 | |||
DefinedBenefitPlanAccumulatedOtherComprehensiveIncomeAndRegulatoryAssetsAcqusition | 0 | 0 | [1] | 994 | |||
Total recognized in AOCI and regulatory assets (liabilities) | [1] | (3) | (824) | 1,010 | |||
Defined benefit plan, amounts recognized in OCI, before tax | 3 | (401) | [1] | 51 | |||
Defined benefit plan, amounts recognized in regulatory assets, before tax | (6) | (423) | [1] | 959 | |||
Pension Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Current year actuarial (gain) loss | $ 0 | ||||||
Amortization of actuarial loss | (14) | ||||||
Amortization of prior service (cost) credit | 0 | ||||||
Total recognized in AOCI and regulatory assets (liabilities) | [1] | (14) | |||||
Defined benefit plan, amounts recognized in OCI, before tax | (1) | ||||||
Defined benefit plan, amounts recognized in regulatory assets, before tax | (13) | ||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Current year actuarial (gain) loss | (232) | 166 | [1] | (101) | |||
Amortization of actuarial loss | (66) | (61) | [1] | (63) | |||
Current year prior service cost (credit) | 0 | 0 | [1] | 0 | |||
Amortization of prior service (cost) credit | 186 | 188 | [1] | 185 | |||
Settlements | 0 | 0 | [1] | 0 | |||
DefinedBenefitPlanAccumulatedOtherComprehensiveIncomeAndRegulatoryAssetsAcqusition | 0 | 0 | [1] | 94 | |||
Total recognized in AOCI and regulatory assets (liabilities) | [1] | (112) | 293 | 115 | |||
Defined benefit plan, amounts recognized in OCI, before tax | (55) | 168 | [1] | 20 | |||
Defined benefit plan, amounts recognized in regulatory assets, before tax | $ (57) | $ 125 | [1] | $ 95 | |||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||
Defined Benefit Plan Disclosure [Line Items] | |||||||
Current year actuarial (gain) loss | 0 | ||||||
Amortization of actuarial loss | (2) | ||||||
Amortization of prior service (cost) credit | 3 | ||||||
Total recognized in AOCI and regulatory assets (liabilities) | [1] | 1 | |||||
Defined benefit plan, amounts recognized in OCI, before tax | 0 | ||||||
Defined benefit plan, amounts recognized in regulatory assets, before tax | $ 1 | ||||||
[1] | 2016 amounts include PHI for the period of March 24, 2016 through December 31, 2016. |
Retirement Benefits Retiremen_6
Retirement Benefits Retirement Benefits - Gross Accumulated Other Comprehensive Loss and Regulatory Assets (Liabilities) not Recognized as Components of Periodic Benefit Cost (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 |
Pension Plan, Defined Benefit [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Prior service (credit) cost | $ (29) | $ (24) |
Actuarial loss | 7,558 | 7,556 |
Total | 7,529 | 7,532 |
Benefits included in accumulated other comprehensive income | 3,899 | 3,896 |
Benefits included in regulatory assets | 3,630 | 3,636 |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ||
Defined Benefit Plan Disclosure [Line Items] | ||
Prior service (credit) cost | (337) | (522) |
Actuarial loss | 531 | 829 |
Total | 194 | 307 |
Benefits included in accumulated other comprehensive income | 70 | 125 |
Benefits included in regulatory assets | $ 124 | $ 182 |
Retirement Benefits Retiremen_7
Retirement Benefits Retirement Benefits - Assumptions Used in Calculations (Details) | 3 Months Ended | 12 Months Ended | ||||||||
Mar. 23, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Mar. 24, 2016 | [8] | |||||
CENG Legacy Benefit Plans [Member] | Minimum [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan Assumptions Used Calculating Net Periodic Benefit Cost Discount Rate Design Changes | 3.49% | 3.66% | 3.68% | |||||||
CENG Legacy Benefit Plans [Member] | Maximum [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan Assumptions Used Calculating Net Periodic Benefit Cost Discount Rate Design Changes | 3.65% | 4.11% | 4.14% | |||||||
Pension Plan, Defined Benefit [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Net Periodic Benefit Cost Investment Crediting Rate | 4.00% | 4.46% | 5.31% | |||||||
Benefit Obligation Investment Crediting Rate | 4.46% | 4.00% | 4.46% | |||||||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets | 7.00% | 7.00% | 7.00% | |||||||
Discount rate | 4.31% | [1],[2] | 3.62% | [2],[3] | 4.04% | [4],[5],[6] | ||||
Pension Plan, Defined Benefit [Member] | CENG Legacy Benefit Plans [Member] | Minimum [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan Assumptions Used Calculating Net Periodic Benefit Cost Discount Rate Design Changes | 4.13% | 3.49% | 3.66% | |||||||
Pension Plan, Defined Benefit [Member] | CENG Legacy Benefit Plans [Member] | Maximum [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan Assumptions Used Calculating Net Periodic Benefit Cost Discount Rate Design Changes | 4.36% | 3.65% | 4.11% | |||||||
Pension Plan, Defined Benefit [Member] | Period One [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase | 3.25% | |||||||||
Pension Plan, Defined Benefit [Member] | Period One [Member] | CENG Legacy Benefit Plans [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase | 3.25% | |||||||||
Pension Plan, Defined Benefit [Member] | Period Two [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase | 3.75% | |||||||||
Pension Plan, Defined Benefit [Member] | Period Two [Member] | CENG Legacy Benefit Plans [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase | 3.75% | |||||||||
Pension Plan, Defined Benefit [Member] | Predecessor [Member] | Pepco Holdings LLC [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Rate of compensation increase | 5.00% | |||||||||
Net Periodic Benefit Cost Investment Crediting Rate | 2.89% | |||||||||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets | [7] | 6.50% | ||||||||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase | 5.00% | |||||||||
Qualified Plan [Member] | Predecessor [Member] | Pepco Holdings LLC [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Discount rate | [8] | 4.65% | ||||||||
Non-Qualified Pension Plan [Member] | Predecessor [Member] | Pepco Holdings LLC [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Discount rate | 4.55% | 4.55% | ||||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Health care cost trend rate | 5.00% | 5.00% | 5.50% | |||||||
Ultimate health care cost trend rate | 5.00% | 5.00% | 5.00% | |||||||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets | 6.60% | 6.58% | 6.71% | |||||||
Discount rate | 4.30% | [1],[2] | 3.61% | [2],[3] | 4.04% | [4],[5],[6] | ||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Remeasurement [Member] | Minimum [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan Assumptions Used Calculating Net Periodic Benefit Cost Discount Rate Design Changes | 3.57% | 4.00% | 4.32% | |||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Remeasurement [Member] | Maximum [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan Assumptions Used Calculating Net Periodic Benefit Cost Discount Rate Design Changes | 3.68% | 4.17% | 4.43% | |||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Remeasurement [Member] | CENG Legacy Benefit Plans [Member] | Minimum [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan Assumptions Used Calculating Net Periodic Benefit Cost Discount Rate Design Changes | 4.27% | 3.57% | 4.00% | |||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Remeasurement [Member] | CENG Legacy Benefit Plans [Member] | Maximum [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan Assumptions Used Calculating Net Periodic Benefit Cost Discount Rate Design Changes | 4.38% | 3.68% | 4.17% | |||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Predecessor [Member] | Pepco Holdings LLC [Member] | ||||||||||
Defined Benefit Plan Assumptions Used In Calculations [Line Items] | ||||||||||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Expected Long-term Rate of Return on Plan Assets | [7] | 6.75% | ||||||||
Defined Benefit Plan, Assumptions Used Calculating Net Periodic Benefit Cost, Rate of Compensation Increase | 5.00% | |||||||||
Discount rate | 4.55% | |||||||||
[1] | (a)The discount rates above represent the blended rates used to determine the majority of Exelon’s pension and other postretirement benefits obligations as of December 31, 2018. Certain benefit plans used individual rates ranging from 4.13% - 4.36% and 4.27% - 4.38% for pension and other postretirement plans, respectively. | |||||||||
[2] | (d)3.25% through 2019 and 3.75% thereafter. | |||||||||
[3] | (b)The discount rates above represent the blended rates used to determine the majority of Exelon’s pension and other postretirement benefits obligations as of December 31, 2017. Certain benefit plans used individual rates ranging from 3.49% - 3.65% and 3.57% - 3.68% for pension and other postretirement plans, respectively. | |||||||||
[4] | (c)The discount rates above represent the blended rates used to determine the majority of Exelon’s pension and other postretirement benefits obligations as of December 31, 2016. Certain benefit plans used individual rates ranging from 3.66% - 4.11% and 4.00% - 4.17% for pension and other postretirement plans, respectively. | |||||||||
[5] | (e)The legacy Exelon, CEG and CENG pension and other postretirement plans used a rate of compensation increase of 3.25% through 2019 and 3.75% thereafter, while the legacy PHI pension and other postretirement plans used a weighted-average rate of compensation increase of 5% for all periods. | |||||||||
[6] | (f)Obligation was not remeasured for the PHI predecessor for the period from January 1, 2016, to March 23, 2016. | |||||||||
[7] | (h)Expected return on other postretirement benefit plan assets is pre-tax. | |||||||||
[8] | (g)The discount rate for the qualified and non-qualified pension plans was 4.65% and 4.55%, respectively. |
Retirement Benefits Retiremen_8
Retirement Benefits Retirement Benefits - Contributions made to Pension and Other Postretirement Benefit Plans (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||||||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | $ 383 | $ 405 | $ 397 | |||||||
Expected qualified pension plan contributions | 301 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 25 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 44 | |||||||||
Corporate, Non-Segment [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Expected qualified pension plan contributions | 41 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 7 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 2 | |||||||||
Constellation Legacy Benefit Plans [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [1] | 0 | 21 | 25 | ||||||
Exelon Generation Co L L C [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 139 | 148 | 152 | |||||||
Expected qualified pension plan contributions | 135 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 7 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 13 | |||||||||
Commonwealth Edison Co [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 42 | 41 | 38 | |||||||
Expected qualified pension plan contributions | 65 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 1 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 2 | |||||||||
PECO Energy Co [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 28 | 24 | 30 | |||||||
Expected qualified pension plan contributions | 25 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 1 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 0 | |||||||||
Baltimore Gas and Electric Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 54 | 53 | 49 | |||||||
Expected qualified pension plan contributions | 34 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 1 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 15 | |||||||||
Pepco Holdings LLC [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | (74) | (99) | ||||||||
Expected qualified pension plan contributions | 1 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 8 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 12 | |||||||||
Pepco Holdings LLC [Member] | Corporate, Non-Segment [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Expected qualified pension plan contributions | 1 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 5 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 1 | |||||||||
Pepco Holdings LLC [Member] | Successor [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | $ (86) | |||||||||
Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | $ (4) | |||||||||
Potomac Electric Power Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 17 | 72 | 32 | |||||||
Expected qualified pension plan contributions | 0 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 2 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 10 | |||||||||
Delmarva Power & Light Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 0 | 2 | 22 | |||||||
Expected qualified pension plan contributions | 0 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 1 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 0 | |||||||||
Atlantic City Electric Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 6 | 20 | 17 | |||||||
Expected qualified pension plan contributions | 0 | |||||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 0 | |||||||||
Defined Other Postretirement Benefit Plan Estimated Future Employer Contributions In Next Fiscal Year | 1 | |||||||||
Pension Plan, Defined Benefit [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 337 | [2] | 341 | [2] | 347 | |||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 1,196 | |||||||||
Pension Plan, Defined Benefit [Member] | Corporate, Non-Segment [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [1],[2] | 41 | 38 | 39 | ||||||
Pension Plan, Defined Benefit [Member] | Exelon Generation Co L L C [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [2] | 128 | 137 | 140 | ||||||
Pension Plan, Defined Benefit [Member] | Commonwealth Edison Co [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [2] | 38 | 36 | 33 | ||||||
Pension Plan, Defined Benefit [Member] | PECO Energy Co [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [2] | 28 | 24 | 30 | ||||||
Pension Plan, Defined Benefit [Member] | Baltimore Gas and Electric Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [2] | 40 | 39 | 31 | ||||||
Pension Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 67 | 62 | ||||||||
Pension Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Corporate, Non-Segment [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 4 | [1] | 50 | [2],[3] | 5 | [2],[3] | 17 | [2],[3] | ||
Pension Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Successor [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 74 | |||||||||
Pension Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 4 | |||||||||
Pension Plan, Defined Benefit [Member] | Exelon Legacy Benefit Plans [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 2 | [1] | 4 | 6 | ||||||
Pension Plan, Defined Benefit [Member] | Potomac Electric Power Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [2] | 6 | 62 | 24 | ||||||
Pension Plan, Defined Benefit [Member] | Delmarva Power & Light Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [2] | 0 | 0 | 22 | ||||||
Pension Plan, Defined Benefit [Member] | Atlantic City Electric Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [2] | 6 | 0 | 15 | ||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 46 | 64 | 50 | |||||||
Defined Benefit Plan, Expected Future Benefit Payment, Next Twelve Months | 255 | |||||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Corporate, Non-Segment [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [1] | 5 | 2 | 3 | ||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Exelon Generation Co L L C [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 11 | 11 | 12 | |||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Commonwealth Edison Co [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 4 | 5 | 5 | |||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | PECO Energy Co [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 0 | 0 | 0 | |||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Baltimore Gas and Electric Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 14 | 14 | 18 | |||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | $ 32 | 12 | ||||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Corporate, Non-Segment [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | [3] | 1 | 0 | 2 | ||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Successor [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | $ 12 | |||||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 0 | |||||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Potomac Electric Power Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 11 | 10 | 8 | |||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Delmarva Power & Light Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | 0 | 2 | 0 | |||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | Atlantic City Electric Company [Member] | ||||||||||
Defined Benefit Plan Disclosure [Line Items] | ||||||||||
Pension and non-pension postretirement benefit contributions | $ 0 | $ 20 | $ 2 | |||||||
[1] | )Includes $2 million, $4 million, and $6 million of pension contributions funded by Exelon Corporate, for the years ended December 31, 2018, 2017, and 2016, respectively. | |||||||||
[2] | Exelon's and Generation's pension contributions include $21 million and $25 million related to the legacy CENG plans that was funded by CENG as provided in an Employee Matters Agreement (EMA) between Exelon and CENG for the years ended December 31, 2017 and 2016, respectively | |||||||||
[3] | PHISCO’s pension contributions for the year ended December 31, 2016 include $4 million of contributions made prior to the closing of Exelon’s merger with PHI on March 23, 2016 |
Retirement Benefits Retiremen_9
Retirement Benefits Retirement Benefits - Estimated Future Benefit Payments (Details) $ in Millions | Dec. 31, 2018USD ($) |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |
2,018 | $ 25 |
Pension Plan, Defined Benefit [Member] | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |
2,018 | 1,196 |
2,019 | 1,221 |
2,020 | 1,258 |
2,021 | 1,284 |
2,022 | 1,302 |
2022 through 2026 | 6,770 |
Total estimated future benefit payments through 2028 | 13,031 |
Other Postretirement Benefit Plan, Defined Benefit [Member] | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |
2,018 | 255 |
2,019 | 263 |
2,020 | 269 |
2,021 | 274 |
2,022 | 282 |
2022 through 2026 | 1,483 |
Total estimated future benefit payments through 2028 | $ 2,826 |
Retirement Benefits Retireme_10
Retirement Benefits Retirement Benefits - Allocated Portion of Pension and Postretirement Benefit Plan Costs (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||||||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | $ 583 | $ 643 | $ 621 | ||||||
Corporate, Non-Segment [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | [1] | 57 | 53 | 48 | |||||
Exelon Generation Co L L C [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | [2] | 204 | 227 | 218 | |||||
Commonwealth Edison Co [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | 177 | 176 | 166 | ||||||
PECO Energy Co [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | 18 | 29 | 33 | ||||||
Baltimore Gas and Electric Company [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | 60 | 64 | 68 | ||||||
Pepco Holdings LLC [Member] | Successor [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | $ 67 | ||||||||
Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | $ 94 | 88 | 23 | ||||||
Pepco Holdings LLC [Member] | Corporate, Non-Segment [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | 9 | 34 | [3],[4] | 43 | [3],[4] | 47 | [3],[4] | ||
Potomac Electric Power Company [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | 7 | 15 | [3] | 25 | [3] | 31 | [3] | ||
Delmarva Power & Light Company [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | 4 | 6 | [3] | 13 | [3] | 18 | [3] | ||
Atlantic City Electric Company [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Amount included in capital and operating & maintenance expense | $ 3 | $ 12 | [3] | $ 13 | [3] | $ 15 | [3] | ||
[1] | These amounts primarily represent amounts billed to Exelon’s subsidiaries through intercompany allocations. These amounts are not included in the Generation, ComEd, PECO, BGE, PHI, Pepco, DPL or ACE amounts above. | ||||||||
[2] | FitzPatrick net benefit costs are included for the period after acquisition | ||||||||
[3] | Pepco's, DPL's, ACE's and PHISCO's pension and postretirement benefit costs for the year ended December 31, 2016 include $7 million, $4 million, $3 million and $9 million, respectively, of costs incurred prior to the closing of Exelon’s merger with PHI on March 23, 2016. | ||||||||
[4] | These amounts represent amounts billed to Pepco, DPL and ACE through intercompany allocations. These amounts are not included in Pepco, DPL or ACE amounts above |
Retirement Benefits Retireme_11
Retirement Benefits Retirement Benefits - Pension and Other Postretirement Benefit Plan Target Asset Allocations (Details) | Dec. 31, 2018 | Dec. 31, 2017 | |
Pension Plan, Defined Benefit [Member] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Percentage of Plan Assets | 100.00% | 100.00% | |
Pension Plan, Defined Benefit [Member] | Equity Securities [Member] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Target asset allocation percentage | 35.00% | ||
Percentage of Plan Assets | 32.00% | 35.00% | |
Pension Plan, Defined Benefit [Member] | Fixed Income Securities [Member] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Target asset allocation percentage | 37.00% | ||
Percentage of Plan Assets | 38.00% | 39.00% | |
Pension Plan, Defined Benefit [Member] | Alternative Investments [Member] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Target asset allocation percentage | [1] | 28.00% | |
Percentage of Plan Assets | [1] | 30.00% | 26.00% |
Other Postretirement Benefit Plan, Defined Benefit [Member] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Percentage of Plan Assets | 100.00% | 100.00% | |
Other Postretirement Benefit Plan, Defined Benefit [Member] | Equity Securities [Member] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Target asset allocation percentage | 47.00% | ||
Percentage of Plan Assets | 44.00% | 47.00% | |
Other Postretirement Benefit Plan, Defined Benefit [Member] | Fixed Income Securities [Member] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Target asset allocation percentage | 28.00% | ||
Percentage of Plan Assets | 28.00% | 28.00% | |
Other Postretirement Benefit Plan, Defined Benefit [Member] | Alternative Investments [Member] | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||
Target asset allocation percentage | [1] | 25.00% | |
Percentage of Plan Assets | [1] | 28.00% | 25.00% |
[1] | Alternative investments include private equity, hedge funds, real estate, and private credit |
Retirement Benefits Retireme_12
Retirement Benefits Retirement Benefits - Fair Value Measurements of Pension and Postretirement Benefit Plan Assets (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Derivative, Fair Value, Net | $ 1 | $ 6 | ||||
Derivative, Notional Amount | 5,991 | 3,606 | ||||
Net assets pending transactions excluded | 44 | (2) | ||||
Fair Value, Measurements, Recurring [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [2],[3] | 19,130 | [1] | 21,303 | ||
Alternative Investment, Fair Value Disclosure | 3,433 | 3,534 | ||||
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [2],[3] | 5,463 | [1] | 6,090 | ||
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [2],[3] | 4,581 | [1] | 4,913 | ||
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [2],[3] | 486 | [1] | 458 | ||
Pension Plan, Defined Benefit [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | 16,678 | 18,573 | $ 16,791 | |||
Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | 486 | 458 | 437 | |||
Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | 216 | 232 | 206 | |||
Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Private Placement [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | 268 | 224 | 229 | [4] | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 16,720 | [1] | 18,575 | ||
Alternative Investment, Fair Value Disclosure | [3] | 7,247 | [1] | 8,216 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Cash and Cash Equivalents [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 350 | [1] | 585 | ||
Alternative Investment, Fair Value Disclosure | [3] | 0 | [1] | 0 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Equity Securities [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3],[5] | 5,346 | [1] | 6,644 | ||
Alternative Investment, Fair Value Disclosure | 1,980 | [1],[3],[5] | 3,077 | |||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | US Treasury and Government [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 1,169 | [1] | 1,309 | ||
Alternative Investment, Fair Value Disclosure | [3] | 0 | [1] | 0 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | US Government Agencies Debt Securities [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 59 | [1] | 64 | ||
Alternative Investment, Fair Value Disclosure | [3] | 0 | [1] | 0 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Corporate Debt Securities [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 3,932 | [1] | 4,163 | ||
Alternative Investment, Fair Value Disclosure | [3] | 0 | [1] | 0 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Other Debt Obligations [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3],[5] | 942 | [1] | 1,203 | ||
Alternative Investment, Fair Value Disclosure | [3],[5] | 613 | [1] | 756 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Debt Securities [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 6,102 | [1] | 6,739 | ||
Alternative Investment, Fair Value Disclosure | [3] | 613 | [1] | 756 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Private Equity Funds [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 1,219 | [1] | 1,034 | ||
Alternative Investment, Fair Value Disclosure | [3] | 1,219 | [1] | 1,034 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Hedge Funds [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 1,608 | [1] | 1,770 | ||
Alternative Investment, Fair Value Disclosure | [3] | 1,608 | [1] | 1,770 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Real Estate Funds [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 1,029 | [1] | 884 | ||
Alternative Investment, Fair Value Disclosure | [3] | 1,029 | [1] | 884 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Private Placement [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 1,066 | [1] | 919 | ||
Alternative Investment, Fair Value Disclosure | [3] | 798 | [1] | 695 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 4,710 | [1] | 5,300 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Cash and Cash Equivalents [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 350 | [1] | 585 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3],[5] | 3,364 | [1] | 3,565 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | US Treasury and Government [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 996 | [1] | 1,150 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | US Government Agencies Debt Securities [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 0 | [1] | 0 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Corporate Debt Securities [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3] | 0 | [1] | 0 | ||
Pension Plan, Defined Benefit [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Other Debt Obligations [Member] | ||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ||||||
Defined Benefit Plan, Fair Value of Plan Assets | [3],[5] | 0 | [1] | 0 | ||
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[1] | Effective March 31, 2017, Exelon became sponsor of FitzPatrick's defined benefit pension and other postretirement benefit plans, and assumed FitzPatrick's benefit plan obligations | |||||
[2] | Excludes net liabilities of $44 million and net assets of $2 million at December 31, 2018 and 2017, respectively, which are required to reconcile to the fair value of net plan assets. These items consist primarily of receivables or payables related to pending securities sales and purchases, interest and dividends receivable | |||||
[3] | See Note 11—Fair Value of Financial Assets and Liabilities for a description of levels within the fair value hierarchy | |||||
[4] | (a)Prior year amounts reflect a reclassification from Not subject to leveling into Level 3. | |||||
[5] | Includes derivative instruments of less than $1 million and $6 million, which have a total notional amount of $5,991 million and $3,606 million at December 31, 2018 and 2017, respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the fiscal years ended and do not represent the amount of the company’s exposure to credit or market loss |
Retirement Benefits Retireme_13
Retirement Benefits Retirement Benefits - Reconciliation of Level 3 Assets and Liabilities measured at Fair Value for Pension and Other Postretirement Benefit Plans (Details) - USD ($) $ in Millions | 12 Months Ended | ||||
Dec. 31, 2018 | Dec. 31, 2017 | ||||
Pension Plan, Defined Benefit [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Fair value of net plan assets at beginning of year | $ 18,573 | $ 16,791 | |||
Defined Benefit Plan, Fair Value of Plan Assets | 16,678 | 18,573 | |||
Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Fair value of net plan assets at beginning of year | 458 | 437 | |||
Relating to assets still held at the reporting date | (5) | 40 | |||
Defined Benefit Plan, Plan Assets Level 3 Reconciliation, Increase (Decrease) for Actual Return (Loss) on Plan Assets Sold | (1) | ||||
Defined Benefit Plan Purchases | 54 | 36 | |||
Defined Benefit Plan Sales | 8 | 16 | |||
Settlements | (12) | [1] | (39) | ||
Defined Benefit Plan, Fair Value of Plan Assets | 486 | 458 | |||
Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Fair value of net plan assets at beginning of year | 232 | 206 | |||
Relating to assets still held at the reporting date | (14) | 11 | |||
Defined Benefit Plan, Plan Assets Level 3 Reconciliation, Increase (Decrease) for Actual Return (Loss) on Plan Assets Sold | (1) | ||||
Defined Benefit Plan Purchases | 19 | 31 | |||
Defined Benefit Plan Sales | 8 | 16 | |||
Settlements | (12) | [1] | 0 | ||
Defined Benefit Plan, Fair Value of Plan Assets | 216 | 232 | |||
Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Equity Security Individually Held [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Fair value of net plan assets at beginning of year | 2 | 2 | |||
Relating to assets still held at the reporting date | 0 | 0 | |||
Defined Benefit Plan, Plan Assets Level 3 Reconciliation, Increase (Decrease) for Actual Return (Loss) on Plan Assets Sold | 0 | ||||
Defined Benefit Plan Purchases | 0 | 0 | |||
Defined Benefit Plan Sales | 0 | 0 | |||
Settlements | 0 | [1] | 0 | ||
Defined Benefit Plan, Fair Value of Plan Assets | 2 | 2 | |||
Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Private Placement [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Fair value of net plan assets at beginning of year | 224 | 229 | [2] | ||
Relating to assets still held at the reporting date | 9 | 29 | |||
Defined Benefit Plan, Plan Assets Level 3 Reconciliation, Increase (Decrease) for Actual Return (Loss) on Plan Assets Sold | 0 | ||||
Defined Benefit Plan Purchases | 35 | 5 | |||
Defined Benefit Plan Sales | 0 | 0 | |||
Settlements | 0 | [1] | (39) | ||
Defined Benefit Plan, Fair Value of Plan Assets | 268 | 224 | |||
Fair Value, Measurements, Recurring [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Alternative Investment, Fair Value Disclosure | 3,433 | 3,534 | |||
Fair value of net plan assets at beginning of year | [3],[4] | 21,303 | |||
Defined Benefit Plan, Fair Value of Plan Assets | [3],[4] | 19,130 | [5] | 21,303 | |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Fair value of net plan assets at beginning of year | [3],[4] | 458 | |||
Defined Benefit Plan, Fair Value of Plan Assets | [3],[4] | 486 | [5] | 458 | |
Fair Value, Measurements, Recurring [Member] | Pension Plan, Defined Benefit [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Alternative Investment, Fair Value Disclosure | [4] | 7,247 | [5] | 8,216 | |
Fair value of net plan assets at beginning of year | [4] | 18,575 | |||
Defined Benefit Plan, Fair Value of Plan Assets | [4] | 16,720 | [5] | 18,575 | |
Fair Value, Measurements, Recurring [Member] | Pension Plan, Defined Benefit [Member] | Debt Securities [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Alternative Investment, Fair Value Disclosure | [4] | 613 | [5] | 756 | |
Fair value of net plan assets at beginning of year | [4] | 6,739 | |||
Defined Benefit Plan, Fair Value of Plan Assets | [4] | 6,102 | [5] | 6,739 | |
Fair Value, Measurements, Recurring [Member] | Pension Plan, Defined Benefit [Member] | Private Placement [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Alternative Investment, Fair Value Disclosure | [4] | 798 | [5] | 695 | |
Fair value of net plan assets at beginning of year | [4] | 919 | |||
Defined Benefit Plan, Fair Value of Plan Assets | [4] | 1,066 | [5] | 919 | |
Fair Value, Measurements, Recurring [Member] | Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Fair value of net plan assets at beginning of year | [4] | 458 | |||
Defined Benefit Plan, Fair Value of Plan Assets | [4] | 486 | [5] | 458 | |
Fair Value, Measurements, Recurring [Member] | Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Fair value of net plan assets at beginning of year | [4] | 232 | |||
Defined Benefit Plan, Fair Value of Plan Assets | [4] | 216 | [5] | 232 | |
Fair Value, Measurements, Recurring [Member] | Pension Plan, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Private Placement [Member] | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||
Fair value of net plan assets at beginning of year | [4] | 224 | |||
Defined Benefit Plan, Fair Value of Plan Assets | [4] | $ 268 | [5] | $ 224 | |
[1] | (b)Represents cash settlements only. | ||||
[2] | (a)Prior year amounts reflect a reclassification from Not subject to leveling into Level 3. | ||||
[3] | Excludes net liabilities of $44 million and net assets of $2 million at December 31, 2018 and 2017, respectively, which are required to reconcile to the fair value of net plan assets. These items consist primarily of receivables or payables related to pending securities sales and purchases, interest and dividends receivable | ||||
[4] | See Note 11—Fair Value of Financial Assets and Liabilities for a description of levels within the fair value hierarchy | ||||
[5] | Effective March 31, 2017, Exelon became sponsor of FitzPatrick's defined benefit pension and other postretirement benefit plans, and assumed FitzPatrick's benefit plan obligations |
Retirement Benefits Retireme_14
Retirement Benefits Retirement Benefits - Summary of Defined Contribution Savings Plan (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||||||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | [1] | $ 179 | $ 128 | $ 164 | |||||
Employer contributions | 13 | ||||||||
Corporate, Non-Segment [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | [2] | 22 | 9 | 19 | |||||
Exelon Generation Co L L C [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | [1] | 86 | 55 | 79 | |||||
Commonwealth Edison Co [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | 37 | 31 | 34 | ||||||
PECO Energy Co [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | 9 | 10 | 10 | ||||||
Baltimore Gas and Electric Company [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | 12 | 10 | 12 | ||||||
Pepco Holdings LLC [Member] | Corporate, Non-Segment [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | $ 1 | 6 | [3],[4] | 6 | [3],[4] | 6 | [3],[4] | ||
Pepco Holdings LLC [Member] | Successor [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | $ 13 | 13 | |||||||
Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | 10 | 3 | |||||||
Potomac Electric Power Company [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | 1 | 3 | [3] | 3 | [3] | 3 | [3] | ||
Delmarva Power & Light Company [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | $ 1 | 2 | [3] | 2 | [3] | 2 | [3] | ||
Atlantic City Electric Company [Member] | |||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | |||||||||
Savings plan matching contributions | [3] | $ 2 | $ 2 | $ 2 | |||||
[1] | Includes $13 million related to CENG for the year ended December 31, 2016 | ||||||||
[2] | These amounts primarily represent amounts billed to Exelon’s subsidiaries through intercompany allocations. These costs are not included in the Generation, ComEd, PECO, BGE, PHI, Pepco, DPL or ACE amounts above | ||||||||
[3] | Pepco's, DPL's and PHISCO's matching contributions include $1 million, $1 million and $1 million, respectively, of costs incurred prior to the closing of Exelon's merger with PHI on March 23, 2016, which is not included in Exelon's matching contributions for the year ended December 31, 2016 | ||||||||
[4] | These amounts primarily represent amounts billed to Pepco, DPL, and ACE through intercompany allocations. These amounts are not included in Pepco, DPL or ACE amounts above. |
Severance Severance - PHI Merge
Severance Severance - PHI Merger (Details) - PHI Merger [Member] $ in Millions | 12 Months Ended |
Dec. 31, 2016USD ($) | |
Restructuring Cost and Reserve [Line Items] | |
Severance Costs | $ 57 |
Exelon Generation Co L L C [Member] | |
Restructuring Cost and Reserve [Line Items] | |
Severance Costs | 9 |
Commonwealth Edison Co [Member] | |
Restructuring Cost and Reserve [Line Items] | |
Severance Costs | 2 |
PECO Energy Co [Member] | |
Restructuring Cost and Reserve [Line Items] | |
Severance Costs | 1 |
Baltimore Gas and Electric Company [Member] | |
Restructuring Cost and Reserve [Line Items] | |
Severance Costs | 1 |
Pepco Holdings LLC [Member] | Successor [Member] | |
Restructuring Cost and Reserve [Line Items] | |
Severance Costs | 44 |
Potomac Electric Power Company [Member] | |
Restructuring Cost and Reserve [Line Items] | |
Severance Costs | 21 |
Delmarva Power & Light Company [Member] | |
Restructuring Cost and Reserve [Line Items] | |
Severance Costs | 13 |
Atlantic City Electric Company [Member] | |
Restructuring Cost and Reserve [Line Items] | |
Severance Costs | $ 10 |
Severance Severance - Liabiliti
Severance Severance - Liabilities Rollforward (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Reserve | $ 77 | $ 94 | $ 88 |
Payments for Restructuring | (29) | ||
Severance [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Severance Costs | 35 | 35 | |
Payments for Restructuring | (52) | ||
Exelon Generation Co L L C [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Reserve | 47 | 58 | 36 |
Payments for Restructuring | (9) | ||
Exelon Generation Co L L C [Member] | Severance [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Severance Costs | 9 | 31 | |
Payments for Restructuring | (20) | ||
Commonwealth Edison Co [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Reserve | 2 | 3 | 3 |
Payments for Restructuring | (2) | ||
Commonwealth Edison Co [Member] | Severance [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Severance Costs | 1 | 2 | |
Payments for Restructuring | (2) | ||
PECO Energy Co [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Reserve | 0 | 0 | 0 |
Payments for Restructuring | 0 | ||
PECO Energy Co [Member] | Severance [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Severance Costs | 0 | 0 | |
Payments for Restructuring | 0 | ||
Baltimore Gas and Electric Company [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Reserve | 1 | 0 | 0 |
Payments for Restructuring | 0 | ||
Baltimore Gas and Electric Company [Member] | Severance [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Severance Costs | 1 | 0 | |
Payments for Restructuring | 0 | ||
Pepco Holdings LLC [Member] | Successor [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Reserve | 7 | 20 | 29 |
Payments for Restructuring | (12) | ||
Pepco Holdings LLC [Member] | Successor [Member] | Severance [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Severance Costs | 5 | 3 | |
Payments for Restructuring | (18) | ||
Potomac Electric Power Company [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Reserve | 0 | 0 | 0 |
Payments for Restructuring | 0 | ||
Potomac Electric Power Company [Member] | Severance [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Severance Costs | 1 | 0 | |
Payments for Restructuring | (1) | ||
Delmarva Power & Light Company [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Reserve | 0 | 0 | 0 |
Payments for Restructuring | 0 | ||
Delmarva Power & Light Company [Member] | Severance [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Severance Costs | 0 | 0 | |
Payments for Restructuring | 0 | ||
Atlantic City Electric Company [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Restructuring Reserve | 0 | 0 | $ 0 |
Payments for Restructuring | 0 | ||
Atlantic City Electric Company [Member] | Severance [Member] | |||
Restructuring Cost and Reserve [Line Items] | |||
Severance Costs | 0 | $ 0 | |
Payments for Restructuring | $ 0 |
Shareholders' Equity Schedule
Shareholders' Equity Schedule of Common Stock Authorized and Outstanding (Details) - $ / shares | Dec. 31, 2018 | Dec. 31, 2017 |
Class of Stock [Line Items] | ||
Common stock, shares authorized | 2,000,000,000 | 2,000,000,000 |
Common stock, shares outstanding | 968,187,955 | 963,335,888 |
Common Stock [Member] | ||
Class of Stock [Line Items] | ||
Common stock, shares authorized | 2,000,000,000 | 2,000,000,000 |
Common Stock [Member] | Commonwealth Edison Co [Member] | ||
Class of Stock [Line Items] | ||
Common Stock, Par or Stated Value Per Share | $ 12.50 | $ 12.50 |
Common stock, shares authorized | 250,000,000 | 250,000,000 |
Common stock, shares outstanding | 127,021,331 | 127,021,246 |
Common Stock [Member] | PECO Energy Co [Member] | ||
Class of Stock [Line Items] | ||
Common stock, shares authorized | 500,000,000 | 500,000,000 |
Common stock, shares outstanding | 170,478,507 | 170,478,507 |
Common Stock [Member] | Baltimore Gas and Electric Company [Member] | ||
Class of Stock [Line Items] | ||
Common stock, shares authorized | 1,500 | 1,500 |
Common stock, shares outstanding | 1,000 | 1,000 |
Common Stock [Member] | Potomac Electric Power Company [Member] | ||
Class of Stock [Line Items] | ||
Common Stock, Par or Stated Value Per Share | $ 0.01 | $ 0.01 |
Common stock, shares authorized | 200,000,000 | 200,000,000 |
Common stock, shares outstanding | 100 | 100 |
Common Stock [Member] | Delmarva Power & Light Company [Member] | ||
Class of Stock [Line Items] | ||
Common Stock, Par or Stated Value Per Share | $ 2.25 | $ 2.25 |
Common stock, shares authorized | 1,000 | 1,000 |
Common stock, shares outstanding | 1,000 | 1,000 |
Common Stock [Member] | Atlantic City Electric Company [Member] | ||
Class of Stock [Line Items] | ||
Common Stock, Par or Stated Value Per Share | $ 3 | $ 3 |
Common stock, shares authorized | 25,000,000 | 25,000,000 |
Common stock, shares outstanding | 8,546,017 | 8,546,017 |
Shareholders' Equity Shareholde
Shareholders' Equity Shareholder Narrative (Details) - USD ($) $ / shares in Units, $ in Millions | Jun. 01, 2017 | Sep. 19, 2016 | Sep. 18, 2016 | Jul. 03, 2016 | Jul. 03, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Jun. 30, 2017 | Jul. 30, 2015 | Jun. 30, 2014 |
Schedule of Capitalization, Equity [Line Items] | |||||||||||
Stock Repurchased During Period, Shares | 33,000,000 | 0 | |||||||||
Temporary Equity, Share Subscriptions | 57,500,000 | 57,500,000 | |||||||||
Sale of Stock, Price Per Share | $ 32.48 | ||||||||||
Treasury Stock, Number of Shares Held | 2,000,000 | 2,000,000 | |||||||||
Treasury stock, at cost | $ 123 | $ 123 | |||||||||
Stock Repurchased During Period, Value | $ 0 | $ 0 | |||||||||
Stock Redeemed or Called During Period, Value | (193) | ||||||||||
Preferred Stock [Member] | |||||||||||
Schedule of Capitalization, Equity [Line Items] | |||||||||||
Preferred Stock, Shares Authorized | 100,000,000 | 100,000,000 | |||||||||
Preferred Stock, Shares Outstanding | 0 | 0 | |||||||||
Equity units issued [Member] | |||||||||||
Schedule of Capitalization, Equity [Line Items] | |||||||||||
Stock Issued During Period, Shares, Treasury Stock Reissued | 33,000,000 | ||||||||||
Minimum [Member] | |||||||||||
Schedule of Capitalization, Equity [Line Items] | |||||||||||
Forward Contract Indexed to Issuer's Equity, Settlement Alternatives, Cash, at Fair Value | $ 1,870 | ||||||||||
Commonwealth Edison Co [Member] | |||||||||||
Schedule of Capitalization, Equity [Line Items] | |||||||||||
Class of Warrant or Right, Outstanding | 60,285 | 60,584 | |||||||||
Commonwealth Edison Co [Member] | Common Stock [Member] | |||||||||||
Schedule of Capitalization, Equity [Line Items] | |||||||||||
Common Stock Shares Reserved For Warrant Conversion | 20,095 | 20,195 | |||||||||
Commonwealth Edison Co [Member] | Preferred Stock [Member] | |||||||||||
Schedule of Capitalization, Equity [Line Items] | |||||||||||
Preferred Stock, Shares Authorized | 850,000 | 850,000 | |||||||||
Preferred Stock, Shares Outstanding | 0 | 0 | |||||||||
Commonwealth Edison Co [Member] | Cumulative Preferred Stock [Member] | |||||||||||
Schedule of Capitalization, Equity [Line Items] | |||||||||||
Preferred Stock, Shares Authorized | 6,810,451 | 6,810,451 | |||||||||
Preferred Stock, Shares Outstanding | 0 | 0 | |||||||||
Baltimore Gas and Electric Company [Member] | |||||||||||
Schedule of Capitalization, Equity [Line Items] | |||||||||||
Preferred Stock, Value, Outstanding | $ 190 | ||||||||||
Preferred Stock, Redemption Price Per Share | $ 100 | ||||||||||
Stock Redeemed or Called During Period, Shares | 400,000 | 500,000 | 400,000 | 600,000 | |||||||
Preferred Stock, Dividend Rate, Percentage | 6.70% | 6.97% | 7.125% | 6.99% | |||||||
Stock Redeemed or Called During Period, Value | $ 90 | $ 100 | $ (190) | ||||||||
Junior Subordinated Debt [Member] | |||||||||||
Schedule of Capitalization, Equity [Line Items] | |||||||||||
Shares Issued, Price Per Share | $ 35 | ||||||||||
Junior Subordinated Notes | $ 1,150 | $ 1,150 | |||||||||
Equity units issued | 23,000,000 | ||||||||||
Stock Issued During Period, Shares, Treasury Stock Reissued | 33,000,000 |
Stock-Based Compensation Plan_3
Stock-Based Compensation Plans - Narrative (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 12 Months Ended | |||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Common Stock Narrative Information [Line Items] | ||||
Obligations of outstanding restricted stock not settled | $ 83 | $ 108 | ||
Settlement of restricted stock | 106 | $ 88 | $ 68 | |
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Share-based Awards Other than Options | $ 33 | |||
Weighted Average Period Non Vested Performance Share Awards Are Expected To Be Recognized Over | 1 year 8 months | |||
Performance Shares [Member] | ||||
Common Stock Narrative Information [Line Items] | ||||
Granted, Weighted Average Grant Date Fair Value (in usd per share) | $ 38.15 | [1] | $ 35 | $ 28.85 |
Percentage to be settled as common stock | 50.00% | |||
Percentage to be settled as cash | 50.00% | |||
Percentage to be settled as cash if ownership requirements are met | 100.00% | |||
Performance Shares [Member] | Pepco Holdings LLC [Member] | ||||
Common Stock Narrative Information [Line Items] | ||||
Granted, Weighted Average Grant Date Fair Value (in usd per share) | 26.10 | |||
Employee Stock Option [Member] | ||||
Common Stock Narrative Information [Line Items] | ||||
Requisite service period | 4 years | |||
Restricted Stock [Member] | ||||
Common Stock Narrative Information [Line Items] | ||||
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition | 1 year 8 months 12 days | |||
Restricted Stock Units (RSUs) [Member] | ||||
Common Stock Narrative Information [Line Items] | ||||
Granted, Weighted Average Grant Date Fair Value (in usd per share) | $ 38.60 | $ 34.98 | $ 28.14 | |
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Share-based Awards Other than Options | $ 38 | |||
Minimum [Member] | Restricted Stock [Member] | ||||
Common Stock Narrative Information [Line Items] | ||||
Requisite service period | 3 years | |||
Maximum [Member] | Restricted Stock [Member] | ||||
Common Stock Narrative Information [Line Items] | ||||
Requisite service period | 5 years | |||
LTIP [Member] | ||||
Common Stock Narrative Information [Line Items] | ||||
Shares authorized | 11 | |||
[1] | (a)As of December 31, 2018, $33 million of total unrecognized compensation costs related to nonvested performance shares are expected to be recognized over the remaining weighted-average period of 1.7 years. |
Stock-Based Compensation Plan_4
Stock-Based Compensation Plans - Schedule of Stock-based Compensation Expense (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||
Mar. 23, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Allocated Share-based Compensation Expense | $ 208 | $ 191 | $ 175 | [1] | |
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense | (18) | ||||
Allocated Share-based Compensation Expense, Net of Tax | 154 | 117 | 107 | [1] | |
Performance Shares [Member] | |||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Allocated Share-based Compensation Expense | 143 | 107 | 93 | [1] | |
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense | (16) | (29) | (18) | ||
Restricted Stock Units (RSUs) [Member] | |||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Allocated Share-based Compensation Expense | 57 | 77 | 75 | [1] | |
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense | (28) | (35) | (27) | ||
Employee Stock Option [Member] | |||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Allocated Share-based Compensation Expense | 0 | 0 | 0 | [1] | |
Stock Compensation Plan [Member] | |||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Allocated Share-based Compensation Expense | 8 | 7 | 7 | [1] | |
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense | $ (54) | $ (74) | $ (68) | [1] | |
Predecessor [Member] | Pepco Holdings LLC [Member] | |||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Allocated Share-based Compensation Expense | $ 3 | ||||
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense | (1) | ||||
Allocated Share-based Compensation Expense, Net of Tax | 2 | ||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Performance Shares [Member] | |||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Allocated Share-based Compensation Expense | 1 | ||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Restricted Stock Units (RSUs) [Member] | |||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Allocated Share-based Compensation Expense | 2 | ||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Employee Stock Option [Member] | |||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Allocated Share-based Compensation Expense | $ 0 | ||||
[1] | (a)2016 amounts include expense related to stock-based compensation granted to eligible PHI employees since the merger date of March 23, 2016. |
Stock-Based Compensation Plan_5
Stock-Based Compensation Plans - Schedule of Pre-Tax Stock-based Compensation Expense (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | ||||
Mar. 23, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Allocated Share-based Compensation Expense | $ 208 | $ 191 | $ 175 | [1] | ||
Exelon Generation Co L L C [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Allocated Share-based Compensation Expense | 77 | 88 | 78 | |||
Commonwealth Edison Co [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Allocated Share-based Compensation Expense | 8 | 7 | 8 | |||
PECO Energy Co [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Allocated Share-based Compensation Expense | 5 | 3 | 3 | |||
Baltimore Gas and Electric Company [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Allocated Share-based Compensation Expense | 3 | 1 | 1 | |||
Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Allocated Share-based Compensation Expense | $ 3 | |||||
Corporate, Non-Segment [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Allocated Share-based Compensation Expense | [2] | 111 | 88 | 81 | ||
Corporate, Non-Segment [Member] | Pepco Holdings LLC [Member] | Successor [Member] | ||||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||||||
Allocated Share-based Compensation Expense | [3],[4] | $ 4 | $ 4 | $ 4 | ||
[1] | (a)2016 amounts include expense related to stock-based compensation granted to eligible PHI employees since the merger date of March 23, 2016. | |||||
[2] | These amounts primarily represent amounts billed to Exelon’s subsidiaries through intercompany allocations. These amounts are not included in the Generation, ComEd, PECO, BGE or PHI amounts above. | |||||
[3] | Pepco's, DPL's and ACE's stock-based compensation expense for the years ended December 31, 2018 and 2017 was not material. | |||||
[4] | These amounts primarily represent amounts billed to PHI’s subsidiaries through PHISCO intercompany allocations. |
Stock-Based Compensation Plan_6
Stock-Based Compensation Plans - Components of Tax Benefits from Stock-based Compensation (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | ||
Mar. 23, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items] | ||||
Tax benefit on stock compensation | $ (18) | |||
Restricted Stock Units (RSUs) [Member] | ||||
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items] | ||||
Tax benefit on stock compensation | $ (28) | $ (35) | (27) | |
Performance Shares [Member] | ||||
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items] | ||||
Tax benefit on stock compensation | $ (16) | $ (29) | $ (18) | |
Pepco Holdings LLC [Member] | Predecessor [Member] | ||||
Deferred Compensation Arrangement with Individual, Share-based Payments [Line Items] | ||||
Tax benefit on stock compensation | $ (1) |
Stock-Based Compensation Plan_7
Stock-Based Compensation Plans - Summary of Stock Option Activity (Details) - Employee Stock Option [Member] - USD ($) $ / shares in Units, $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding [Roll Forward] | |||
Beginning Balance | 6,723,611 | ||
Options exercised | (1,522,952) | ||
Options forfeited | 0 | ||
Options expired | (1,173,007) | ||
Ending Balance | 4,027,652 | 6,723,611 | |
Weighted Average Exercise Price (in usd per share) | $ 43.95 | $ 47.69 | |
Options Exercised, Weighted Average Exercise Price (in usd per share) | 36.54 | ||
Options Forfeited, Weighted Average Exercise Price (in usd per share) | 0 | ||
Options Expired, Weighted Average Exercise Price (in usd per share) | $ 74.99 | ||
Shares Outstanding, Weighted Average Remaining Contractual Life | 2 years 10 months 24 days | 2 years 7 months 24 days | |
Exercisable at December 31, 2017 | [1] | 4,027,652 | |
Shares Exercisable, Weighted Average Exercise Price (in usd per share) | [1] | $ 43.95 | |
Shares Exercisable, Weighted Average Remaining Contractual Life | [1] | 2 years 10 months 24 days | |
Share-based Compensation Arrangement by Share-based Payment Award, Options, Outstanding, Intrinsic Value | $ 14 | $ 7 | |
Shares Exercisable, Aggregate Intrinsic Value | [1] | $ 14 | |
[1] | Includes stock options issued to retirement eligible employees. |
Stock-Based Compensation Plan_8
Stock-Based Compensation Plans - Summary of Information of Stock Options Exercised (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Common Stock [Abstract] | ||||
Aggregate value | [1] | $ 12 | $ 15 | $ 11 |
Cash received for exercise price | $ 56 | $ 107 | $ 19 | |
[1] | The difference between the market value on the date of exercise and the option exercise price. |
Stock-Based Compensation Plan_9
Stock-Based Compensation Plans - Summary of Nonvested Restricted Stock Unit Activity (Details) - Restricted Stock Units (RSUs) [Member] - $ / shares | 12 Months Ended | |||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward] | ||||
Beginning Balance | [1] | 3,389,503 | ||
Granted | 1,321,988 | |||
Vested | (1,845,300) | |||
Forfeited | (65,046) | |||
Undistributed vested awards | [2] | (507,804) | ||
Ending Balance | [1] | 2,293,341 | 3,389,503 | |
Nonvested, Weighted Average Exercise Price (in usd per share) | [1] | $ 32.24 | ||
Granted, Weighted Average Grant Date Fair Value (in usd per share) | 38.60 | $ 34.98 | $ 28.14 | |
Vested, Weighted Average Exercise Price (in usd per share) | 32.03 | |||
Forfeited, Weighted Average Exercise Price (in usd per share) | 32.96 | |||
Undistributed Vested Awards, Weighted Average Grant Date Fair Value (in usd per share) | [2] | 36.76 | ||
Nonvested, Weighted Average Exercise Price (in usd per share) | [1] | $ 35.06 | $ 32.24 | |
Fully Vested Stock Based Compensation Issued To Retirement Eligible Employees | 1,131,487 | 1,488,383 | ||
[1] | Excludes 1,131,487 and 1,488,383 of restricted stock units issued to retirement-eligible employees as of December 31, 2018 and 2017, respectively, as they are fully vested. | |||
[2] | Represents restricted stock units that vested but were not distributed to retirement-eligible employees during 2018. |
Stock-Based Compensation Pla_10
Stock-Based Compensation Plans - Summary of Nonvested Performance Share Awards Activity (Details) - USD ($) $ / shares in Units, $ in Millions | 12 Months Ended | ||||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward] | |||||
Employee Service Share-based Compensation, Nonvested Awards, Compensation Not yet Recognized, Share-based Awards Other than Options | $ 33 | ||||
Weighted Average Period Non Vested Performance Share Awards Are Expected To Be Recognized Over | 1 year 8 months | ||||
Fair Value Of Settled Performance Share Awards | $ 61 | [1] | $ 72 | $ 45 | |
Performance Share Awards Obligations Settled In Cash | $ 49 | [1] | $ 56 | $ 28 | |
Performance Shares [Member] | |||||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward] | |||||
Beginning Balance | [2] | 2,956,966 | |||
Granted | 1,637,542 | ||||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Period Increase (Decrease) | 1,348,029 | ||||
Vested | (848,574) | ||||
Forfeited | (50,467) | ||||
Undistributed vested awards | [3] | (1,640,268) | |||
Ending Balance | [2] | 3,403,228 | 2,956,966 | ||
Nonvested, Weighted Average Exercise Price (in usd per share) | [2] | $ 33.13 | $ 32.65 | ||
Granted, Weighted Average Grant Date Fair Value (in usd per share) | 38.15 | [1] | $ 35 | $ 28.85 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Change in Performance, Weighted Average Grant Date Fair Value | 30.66 | ||||
Vested, Weighted Average Exercise Price (in usd per share) | 36.26 | ||||
Forfeited, Weighted Average Exercise Price (in usd per share) | 36.24 | ||||
Undistributed Vested Awards, Weighted Average Grant Date Fair Value (in usd per share) | [3] | $ 33.38 | |||
Fully Vested Stock Based Compensation Issued To Retirement Eligible Employees | 3,586,259 | 2,723,440 | |||
Performance Shares [Member] | Pepco Holdings LLC [Member] | |||||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number of Shares [Roll Forward] | |||||
Granted, Weighted Average Grant Date Fair Value (in usd per share) | $ 26.10 | ||||
[1] | (a)As of December 31, 2018, $33 million of total unrecognized compensation costs related to nonvested performance shares are expected to be recognized over the remaining weighted-average period of 1.7 years. | ||||
[2] | Excludes 3,586,259 and 2,723,440 of performance share awards issued to retirement-eligible employees as of December 31, 2018 and 2017, respectively, as they are fully vested. | ||||
[3] | Represents performance share awards that vested but were not distributed to retirement-eligible employees during 2018. |
Stock-Based Compensation Pla_11
Stock-Based Compensation Plans - Balance Sheet Classification of Obligations related to Outstanding Performance Share Awards Not Yet Settled (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||
Classification Of Obligations Related To Outstanding Performance Share Awards Not Yet Settled Current Liabilities | [1] | $ 135 | $ 57 |
Classification Of Obligations Related To Outstanding Performance Share Awards Not Yet Settled Deferred Credits And Other Liabilities | [2] | 109 | 100 |
Classification Of Obligations Related To Outstanding Performance Share Awards Not Yet Settled Common Stock | 26 | 26 | |
Total Balance Sheet Classification Of Obligations Related To Outstanding Performance Share Awards Not Yet Settled | $ 270 | $ 183 | |
[1] | Represents the current liability related to performance share awards expected to be settled in cash. | ||
[2] | Represents the long-term liability related to performance share awards expected to be settled in cash. |
Earnings Per Share Earnings P_2
Earnings Per Share Earnings Per Share - Schedule of Earnings per Share (Details) - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 12 Months Ended | |||||||||
Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2017 | Jun. 30, 2017 | Mar. 31, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Earnings Per Share [Abstract] | |||||||||||
Net income (loss) attributable to common shareholders | $ 152 | $ 733 | $ 539 | $ 585 | $ 1,880 | $ 823 | $ 95 | $ 990 | $ 2,010 | $ 3,786 | $ 1,121 |
Weighted average common shares outstanding — basic | 967 | 947 | 924 | ||||||||
Assumed exercise and/or distributions of stock-based awards | 2 | 2 | 3 | ||||||||
Weighted average common shares outstanding — diluted | 969 | 949 | 927 |
Earnings Per Share Earnings P_3
Earnings Per Share Earnings Per Share - Narrative (Details) - shares shares in Millions | Jun. 01, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 |
Equity units issued [Member] | ||||
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items] | ||||
Stock Issued During Period, Shares, Treasury Stock Reissued | 33 | |||
Pepco Holdings [Member] | ||||
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items] | ||||
Stock options not included in the calculation of diluted common shares outstanding (less than 1 million related to PHI merger) | 0 | 0 | 0 | |
Employee Stock Option [Member] | ||||
Earnings Per Share, Diluted, by Common Class, Including Two Class Method [Line Items] | ||||
Stock options not included in the calculation of diluted common shares outstanding (less than 1 million related to PHI merger) | 3 | 8 | 12 |
Changes in Accumulated Other _3
Changes in Accumulated Other Comprehensive Income Changes in Accumulated Other Comprehensive Income - Schedule of Changes in AOCI (Details) - USD ($) $ in Millions | 12 Months Ended | |||||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | $ 32,187 | $ 27,640 | $ 27,330 | |||
Amounts reclassified from AOCI | [1] | 182 | 144 | |||
Other comprehensive income (loss) | 42 | 171 | (36) | |||
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings | 539 | |||||
Ending Balance | 33,070 | 32,187 | 27,640 | |||
Gains and (Losses) on Cash Flow Hedges | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | (14) | (17) | |||
OCI before reclassifications | [2] | 11 | (1) | |||
Amounts reclassified from AOCI | [2],[3] | 1 | 4 | |||
Other comprehensive income (loss) | [2] | 12 | 3 | |||
Ending Balance | [2] | (2) | (14) | (17) | ||
Gains and (Losses) on Cash Flow Hedges | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
Unrealized Gains and (losses) on Marketable Securities | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | 10 | 4 | |||
OCI before reclassifications | [2] | 0 | 6 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 0 | 6 | |||
Ending Balance | [2] | 0 | 10 | 4 | ||
Unrealized Gains and (losses) on Marketable Securities | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | (10) | ||||
Pension and Non-Pension Postretirement Benefit Plan Items | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | (2,998) | (2,610) | |||
OCI before reclassifications | [2] | (143) | 11 | |||
Amounts reclassified from AOCI | [1],[2],[3] | 181 | 140 | |||
Other comprehensive income (loss) | [2] | 38 | 151 | |||
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings | [2],[5] | (539) | ||||
Ending Balance | [2] | (2,960) | (2,998) | (2,610) | ||
Pension and Non-Pension Postretirement Benefit Plan Items | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
Foreign Currency Items | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | (23) | (30) | |||
OCI before reclassifications | [2] | (10) | 7 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | (10) | 7 | |||
Ending Balance | [2] | (33) | (23) | (30) | ||
Foreign Currency Items | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
AOCI of Investments Unconsolidated Affiliates | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | (1) | (7) | |||
OCI before reclassifications | [2] | 1 | 6 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 1 | 6 | |||
Ending Balance | [2] | 0 | (1) | (7) | ||
AOCI of Investments Unconsolidated Affiliates | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
Total | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | (3,026) | [2] | (2,660) | [2] | (2,624) | |
OCI before reclassifications | [2] | (141) | 29 | |||
Amounts reclassified from AOCI | [2],[3] | 182 | 144 | |||
Other comprehensive income (loss) | 41 | [2] | 173 | [2] | (36) | |
Tax Cuts and Jobs Act, Reclassification from AOCI to Retained Earnings | [2],[5] | (539) | ||||
Ending Balance | [2] | (2,995) | (3,026) | (2,660) | ||
Total | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | (10) | ||||
Exelon Generation Co L L C [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Amounts reclassified from AOCI | [1] | 1 | 4 | |||
Other comprehensive income (loss) | 3 | 15 | 9 | |||
Exelon Generation Co L L C [Member] | Gains and (Losses) on Cash Flow Hedges | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | (16) | (19) | |||
OCI before reclassifications | [2] | 11 | (1) | |||
Amounts reclassified from AOCI | [2],[3] | 1 | 4 | |||
Other comprehensive income (loss) | [2] | 12 | 3 | |||
Ending Balance | [2] | (4) | (16) | (19) | ||
Exelon Generation Co L L C [Member] | Gains and (Losses) on Cash Flow Hedges | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
Exelon Generation Co L L C [Member] | Unrealized Gains and (losses) on Marketable Securities | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | 3 | 2 | |||
OCI before reclassifications | [2] | 0 | 1 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 0 | 1 | |||
Ending Balance | [2] | 0 | 3 | 2 | ||
Exelon Generation Co L L C [Member] | Unrealized Gains and (losses) on Marketable Securities | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | (3) | ||||
Exelon Generation Co L L C [Member] | Pension and Non-Pension Postretirement Benefit Plan Items | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | 0 | 0 | |||
OCI before reclassifications | [2] | 0 | 0 | |||
Amounts reclassified from AOCI | [1],[2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 0 | 0 | |||
Ending Balance | [2] | 0 | 0 | 0 | ||
Exelon Generation Co L L C [Member] | Pension and Non-Pension Postretirement Benefit Plan Items | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
Exelon Generation Co L L C [Member] | Foreign Currency Items | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | (23) | (30) | |||
OCI before reclassifications | [2] | (10) | 7 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | (10) | 7 | |||
Ending Balance | [2] | (33) | (23) | (30) | ||
Exelon Generation Co L L C [Member] | Foreign Currency Items | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
Exelon Generation Co L L C [Member] | AOCI of Investments Unconsolidated Affiliates | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | (1) | (7) | |||
OCI before reclassifications | [2] | 0 | 6 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 0 | 6 | |||
Ending Balance | [2] | (1) | (1) | (7) | ||
Exelon Generation Co L L C [Member] | AOCI of Investments Unconsolidated Affiliates | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
Exelon Generation Co L L C [Member] | Total | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | (37) | (54) | |||
OCI before reclassifications | [2] | 1 | 13 | |||
Amounts reclassified from AOCI | [2],[3] | 1 | 4 | |||
Other comprehensive income (loss) | 2 | [2] | 17 | [2] | 9 | |
Ending Balance | [2] | (38) | (37) | (54) | ||
Exelon Generation Co L L C [Member] | Total | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | (3) | ||||
PECO Energy Co [Member] | Gains and (Losses) on Cash Flow Hedges | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | 0 | 0 | |||
OCI before reclassifications | [2] | 0 | 0 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 0 | 0 | |||
Ending Balance | [2] | 0 | 0 | 0 | ||
PECO Energy Co [Member] | Gains and (Losses) on Cash Flow Hedges | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
PECO Energy Co [Member] | Unrealized Gains and (losses) on Marketable Securities | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | 1 | 1 | |||
OCI before reclassifications | [2] | 0 | 0 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 0 | 0 | |||
Ending Balance | [2] | 0 | 1 | 1 | ||
PECO Energy Co [Member] | Unrealized Gains and (losses) on Marketable Securities | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | (1) | ||||
PECO Energy Co [Member] | Pension and Non-Pension Postretirement Benefit Plan Items | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | 0 | 0 | |||
OCI before reclassifications | [2] | 0 | 0 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 0 | 0 | |||
Ending Balance | [2] | 0 | 0 | 0 | ||
PECO Energy Co [Member] | Pension and Non-Pension Postretirement Benefit Plan Items | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
PECO Energy Co [Member] | Foreign Currency Items | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | 0 | 0 | |||
OCI before reclassifications | [2] | 0 | 0 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 0 | 0 | |||
Ending Balance | [2] | 0 | 0 | 0 | ||
PECO Energy Co [Member] | Foreign Currency Items | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
PECO Energy Co [Member] | AOCI of Investments Unconsolidated Affiliates | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | 0 | 0 | |||
OCI before reclassifications | [2] | 0 | 0 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 0 | 0 | |||
Ending Balance | [2] | 0 | 0 | 0 | ||
PECO Energy Co [Member] | AOCI of Investments Unconsolidated Affiliates | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | 0 | ||||
PECO Energy Co [Member] | Total | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Beginning Balance | [2] | 1 | 1 | |||
OCI before reclassifications | [2] | 0 | 0 | |||
Amounts reclassified from AOCI | [2],[3] | 0 | 0 | |||
Other comprehensive income (loss) | [2] | 0 | 0 | |||
Ending Balance | [2] | 0 | $ 1 | $ 1 | ||
PECO Energy Co [Member] | Total | Accounting Standards Update 2016-01 [Member] | ||||||
Movement in Accumulated Other Comprehensive Income [Roll Forward] | ||||||
Impact of adoption of Recognition and Measurement of Financial Assets and Liabilities standard | [2],[4] | $ (1) | ||||
[1] | Amounts in parenthesis represent a decrease in net income. | |||||
[2] | All amounts are net of tax and noncontrolling interests. Amounts in parenthesis represent a decrease in AOCI. | |||||
[3] | See next tables for details about these reclassifications. | |||||
[4] | Exelon prospectively adopted the new standard Recognition and Measurement of Financial Assets and Financial Liabilities. The standard was adopted as of January 1, 2018, which resulted in an increase to Retained earnings and Accumulated other comprehensive loss of $10 million, $3 million and $1 million for Exelon, Generation and PECO, respectively. The amounts reclassified related to Rabbi Trusts. See Note 1 — Significant Accounting Policies for additional information. | |||||
[5] | Exelon early adopted the new standard Reclassification of Certain Tax Effects from AOCI. The standard was adopted retrospectively as of December 31, 2017, which resulted in an increase to Exelon’s Retained earnings and Accumulated other comprehensive loss of $539 million, primarily related to deferred income taxes associated with Exelon’s pension and OPEB obligations. See Note 1 — Significant Accounting Policies for additional information. |
Changes in Accumulated Other _4
Changes in Accumulated Other Comprehensive Income Changes in Accumulated Other Comprehensive Income - Reclassifications out of Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | ||||
Dec. 31, 2018 | Mar. 23, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Loss | $ (112) | $ 947 | $ 297 | |||
Income Tax Expense (Benefit) | $ 26 | 120 | (126) | 753 | ||
Net income (loss) | 2,084 | 3,876 | 1,196 | |||
Amortization of pension and other postretirement benefit plan items | 4 | |||||
Amounts reclassified from AOCI | [1] | (182) | (144) | |||
Reclassification out of Accumulated Other Comprehensive Income [Member] | Cash Flow Hedging [Member] | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Income Tax Expense (Benefit) | (1) | |||||
Gains and (Losses) on Cash Flow Hedges | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Amounts reclassified from AOCI | [2],[3] | (1) | (4) | |||
Gains and (Losses) on Cash Flow Hedges | Reclassification out of Accumulated Other Comprehensive Income [Member] | Cash Flow Hedging [Member] | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Other cash flow hedges | [1] | (1) | (5) | |||
Total before tax | [1] | (1) | (5) | |||
Income Tax Expense (Benefit) | [1] | 0 | 1 | |||
Net of tax | [1] | (1) | (4) | |||
Prior service costs | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Amortization of pension and other postretirement benefit plan items | [1],[4] | 90 | 92 | |||
Actuarial losses | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Amortization of pension and other postretirement benefit plan items | [1],[4] | (333) | (324) | |||
Pension and Non-Pension Postretirement Benefit Plan Items | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Amortization of pension and other postretirement benefit plan items | [1] | (243) | (232) | |||
Tax benefit | [1] | 62 | 92 | |||
Amounts reclassified from AOCI | [1],[2],[3] | (181) | (140) | |||
Exelon Generation Co L L C [Member] | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Loss | (178) | 948 | 401 | |||
Income Tax Expense (Benefit) | (108) | (1,376) | 282 | |||
Net income (loss) | 443 | 2,798 | $ 550 | |||
Amortization of pension and other postretirement benefit plan items | 3 | |||||
Amounts reclassified from AOCI | [1] | (1) | (4) | |||
Exelon Generation Co L L C [Member] | Gains and (Losses) on Cash Flow Hedges | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Amounts reclassified from AOCI | [2],[3] | (1) | (4) | |||
Exelon Generation Co L L C [Member] | Gains and (Losses) on Cash Flow Hedges | Reclassification out of Accumulated Other Comprehensive Income [Member] | Cash Flow Hedging [Member] | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Other cash flow hedges | [1] | (1) | (5) | |||
Total before tax | [1] | (1) | (5) | |||
Income Tax Expense (Benefit) | [1] | 0 | 1 | |||
Net of tax | [1] | (1) | (4) | |||
Exelon Generation Co L L C [Member] | Prior service costs | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Amortization of pension and other postretirement benefit plan items | [1],[4] | 0 | 0 | |||
Exelon Generation Co L L C [Member] | Actuarial losses | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Amortization of pension and other postretirement benefit plan items | [1],[4] | 0 | 0 | |||
Exelon Generation Co L L C [Member] | Pension and Non-Pension Postretirement Benefit Plan Items | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Amortization of pension and other postretirement benefit plan items | [1] | 0 | 0 | |||
Tax benefit | [1] | 0 | 0 | |||
Amounts reclassified from AOCI | [1],[2],[3] | 0 | 0 | |||
Pepco Holdings LLC [Member] | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Loss | 43 | 54 | ||||
Income Tax Expense (Benefit) | 35 | 217 | ||||
Net income (loss) | $ 398 | $ 362 | ||||
Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||||
Loss | $ (4) | |||||
Income Tax Expense (Benefit) | 17 | |||||
Net income (loss) | $ 19 | |||||
[1] | Amounts in parenthesis represent a decrease in net income. | |||||
[2] | All amounts are net of tax and noncontrolling interests. Amounts in parenthesis represent a decrease in AOCI. | |||||
[3] | See next tables for details about these reclassifications. | |||||
[4] | This AOCI component is included in the computation of net periodic pension and OPEB cost. See Note 16 — Retirement Benefits for additional information. |
Changes in Accumulated Other _5
Changes in Accumulated Other Comprehensive Income - Components of Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Tax | $ (17) | $ (90) | $ 30 |
Prior service costs | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Tax | 24 | 36 | 30 |
Actuarial losses | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Tax | (86) | (128) | (118) |
Pension and Non-Pension Postretirement Benefit Plan Items | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Tax | 50 | 13 | 115 |
Gains and (Losses) on Cash Flow Hedges | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Tax | (5) | (7) | 0 |
Unrealized Gains and (losses) on Marketable Securities | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Change in unrealized gains (losses) on investments in unconsolidated affiliates | 0 | (3) | 3 |
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, Tax | 0 | (1) | 0 |
Exelon Generation Co L L C [Member] | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Tax | (5) | (10) | 1 |
Exelon Generation Co L L C [Member] | Gains and (Losses) on Cash Flow Hedges | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Other Comprehensive Income (Loss), Tax | (4) | (6) | (2) |
Exelon Generation Co L L C [Member] | Unrealized Gains and (losses) on Marketable Securities | |||
Accumulated Other Comprehensive Income (Loss) [Line Items] | |||
Change in unrealized gains (losses) on investments in unconsolidated affiliates | (1) | (3) | 3 |
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, Tax | $ 0 | $ (1) | $ 0 |
Commitments and Contingencies C
Commitments and Contingencies Commitments and Contingencies - Narrative (Details) | Nov. 04, 2016 | Nov. 01, 2015USD ($) | Sep. 23, 2015USD ($) | Dec. 31, 2018USD ($)employeeOpen_claimMGPSite | Sep. 30, 2018USD ($) | Dec. 31, 2017USD ($)MW | Dec. 31, 2018USD ($)employeeOpen_claimMGPSiteMW | Dec. 31, 2017USD ($) | Dec. 31, 2016USD ($) | Feb. 17, 2012USD ($) | |
Commitments and Contingencies [Line Items] | |||||||||||
Operating Leases, Future Minimum Payments Due | [1],[2] | $ 1,378,000,000 | $ 1,378,000,000 | ||||||||
Direct Investment Commitment | $ 1,000,000,000 | ||||||||||
Power Volume | MW | 10 | 220 | |||||||||
Business Acquisition Residual Commitment | MW | 55 | ||||||||||
Loss Contingency, Loss in Period | $ 50,000,000 | ||||||||||
Nontrade Receivables, Current | [3] | 124,000,000 | $ 94,000,000 | $ 124,000,000 | 94,000,000 | ||||||
Nontrade Receivables, Noncurrent | [4] | 15,000,000 | 15,000,000 | 15,000,000 | 15,000,000 | ||||||
Accounts Payable, Other, Current | [3],[5] | (17,000,000) | (11,000,000) | (17,000,000) | (11,000,000) | ||||||
DOE Spent Nuclear Fuel One Time Fee | 34,000,000 | 34,000,000 | |||||||||
Operating Expenses | [6] | 32,143,000,000 | 29,619,000,000 | 28,106,000,000 | |||||||
Exelon Generation Co L L C [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Operating Leases, Future Minimum Payments Due | [1],[2] | 763,000,000 | 763,000,000 | ||||||||
Direct Investment Commitment | |||||||||||
Entity Number of Employees | employee | 1,500 | 1,500 | |||||||||
Leasehold Improvements, Gross | $ 90,000,000 | $ 90,000,000 | |||||||||
Lessee, Operating Lease, Term of Contract | 20 years | ||||||||||
Costs Incurred, Development Costs | 458,000,000 | ||||||||||
Nuclear financial protection pool value | 450,000,000 | 450,000,000 | |||||||||
Maximum recovery limit from a nuclear industry mutual insurance company in the event of multiple losses | 13,600,000,000 | 13,600,000,000 | |||||||||
Maximum annual assessment payment mandated by Price-Anderson Act for a nuclear incident | 3,100,000,000 | 3,100,000,000 | |||||||||
Mutual Insurance Total Retrospective Premium Obligation | 345,000,000 | 345,000,000 | |||||||||
Mutual Replacement Power Cost Insurance Maximum Retrospective Premium Obligation | 3,200,000,000 | 3,200,000,000 | |||||||||
Cost of spent nuclear fuel disposal per kWh of net nuclear generation | 0.001 | 0.001 | |||||||||
Spent Nuclear Fuel Storage Reimbursement | [7] | 1,274,000,000 | |||||||||
Spent Nuclear Fuel Storage Reimbursement Net Co Owners | [7],[8] | 1,100,000,000 | |||||||||
DOE Spent Nuclear Fuel One Time Fee | 277,000,000 | 277,000,000 | |||||||||
DOE Spent Nuclear Fuel One Time Fee With Interest | 1,171,000,000 | 1,147,000,000 | $ 1,171,000,000 | 1,147,000,000 | |||||||
Spent Nuclear Fuel Treasury Interest Rate | 2.351% | ||||||||||
Loss Contingency Accrual, Provision | 20,000,000 | ||||||||||
Environmental loss contingencies | 90,000,000 | 90,000,000 | |||||||||
Asbestos Liability Reserve | $ 79,000,000 | 78,000,000 | $ 79,000,000 | 78,000,000 | |||||||
Open Asbestos Liability Claims | Open_claim | 238 | 238 | |||||||||
Exelon Generation Co L L C [Member] | Minimum [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Direct Investment Commitment | $ 450,000,000 | $ 450,000,000 | |||||||||
Business Acquisition, Expected New Generation Mwh | MW | 285 | ||||||||||
Exelon Generation Co L L C [Member] | Maximum [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Direct Investment Commitment | 500,000,000 | $ 500,000,000 | |||||||||
Business Acquisition, Expected New Generation Mwh | MW | 300 | ||||||||||
Exelon Generation Co L L C [Member] | West Lake [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Loss Contingency Accrual, Provision | 280,000,000 | ||||||||||
Exelon Generation Co L L C [Member] | Nuclear Insurance Premiums [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Nuclear insurance liability limit per incident | 14,100,000,000 | $ 14,100,000,000 | |||||||||
Exelon Generation Co L L C [Member] | Nuclear Insurance Premiums [Member] | Maximum [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Nuclear financial protection pool value | $ 454,000,000 | ||||||||||
Exelon Generation Co L L C [Member] | Guarantees Other Than Letters Of Credit and Nuclear Insurance Premiums [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Mutual Property Insurance Distribution To Members | 58,000,000 | 60,000,000 | 58,000,000 | 60,000,000 | $ 21,000,000 | ||||||
Commonwealth Edison Co [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Operating Leases, Future Minimum Payments Due | [2],[9] | 23,000,000 | 23,000,000 | ||||||||
Direct Investment Commitment | |||||||||||
Total number of MGP sites | MGPSite | 42 | 42 | |||||||||
Sites approved for clean-up | MGPSite | 21 | 21 | |||||||||
Sites under study/remediation | MGPSite | 21 | 21 | |||||||||
Other Increase (Decrease) in Environmental Liabilities | $ 48,000,000 | ||||||||||
PECO Energy Co [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Operating Leases, Future Minimum Payments Due | [2],[9] | $ 25,000,000 | $ 25,000,000 | ||||||||
Direct Investment Commitment | |||||||||||
Total number of MGP sites | MGPSite | 26 | 26 | |||||||||
Sites approved for clean-up | MGPSite | 17 | 17 | |||||||||
Sites under study/remediation | MGPSite | 9 | 9 | |||||||||
Baltimore Gas and Electric Company [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Operating Leases, Future Minimum Payments Due | [2],[9],[10],[11] | $ 143,000,000 | $ 143,000,000 | ||||||||
Direct Investment Commitment | |||||||||||
Total number of MGP sites | MGPSite | 13 | 13 | |||||||||
Sites approved for clean-up | MGPSite | 9 | 9 | |||||||||
Sites under study/remediation | MGPSite | 4 | 4 | |||||||||
Common Equity Tier One Capital Ratio | 48.00% | 48.00% | |||||||||
Occupancy, Net | $ 42,000,000 | $ 12,000,000 | |||||||||
Operating Leases, Income Statement, Initial Direct Costs | 25,000,000 | ||||||||||
Oil and Gas Property, Lease Operating Expense | 29,000,000 | ||||||||||
Operating Expenses | 28,000,000 | ||||||||||
Pepco Holdings LLC [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Operating Leases, Future Minimum Payments Due | [2] | $ 377,000,000 | $ 377,000,000 | ||||||||
Direct Investment Commitment | |||||||||||
Potomac Electric Power Company [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Operating Leases, Future Minimum Payments Due | [2] | 86,000,000 | 86,000,000 | ||||||||
Direct Investment Commitment | |||||||||||
Accrued Liabilities and Other Liabilities | 30,000,000 | 28,000,000 | 30,000,000 | 28,000,000 | |||||||
Delmarva Power & Light Company [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Operating Leases, Future Minimum Payments Due | [2],[9] | 96,000,000 | 96,000,000 | ||||||||
Direct Investment Commitment | |||||||||||
Total number of MGP sites | MGPSite | 3 | 3 | |||||||||
Sites approved for clean-up | MGPSite | 2 | 2 | |||||||||
Common Equity Tier One Capital Ratio | 48.00% | 48.00% | |||||||||
Atlantic City Electric Company [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Operating Leases, Future Minimum Payments Due | [2] | $ 32,000,000 | $ 32,000,000 | ||||||||
Direct Investment Commitment | |||||||||||
Common Equity Tier One Capital Ratio | 30.00% | 30.00% | |||||||||
Open Claims [Member] | Exelon Generation Co L L C [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Asbestos Liability Reserve | $ 24,000,000 | $ 24,000,000 | |||||||||
Estimated Future Claims [Member] | Exelon Generation Co L L C [Member] | |||||||||||
Commitments and Contingencies [Line Items] | |||||||||||
Asbestos Liability Reserve | $ 55,000,000 | $ 55,000,000 | |||||||||
[1] | )Excludes Generation’s contingent operating lease payments associated with contracted generation agreement | ||||||||||
[2] | )Includes amounts related to shared use land arrangement | ||||||||||
[3] | )Recorded in Accounts receivable, other. | ||||||||||
[4] | )Recorded in Deferred debits and other assets, oth | ||||||||||
[5] | )Non-CENG amounts owed to co-owners are recorded in Accounts receivable, other. CENG amounts owed to co-owners are recorded in Accounts payable. Represents amounts owed to the co-owners of Peach Bottom, Quad Cities, and Nine Mile Point Unit 2 generating facilities | ||||||||||
[6] | Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 23 — Supplemental Financial Information for additional information on total utility taxes. | ||||||||||
[7] | )Includes $53 and $49, respectively, for amounts received since April 1, 2014, for costs incurred under the CENG DOE Settlement Agreements prior to the consolidation of CEN | ||||||||||
[8] | )Total after considering amounts due to co-owners of certain nuclear stations and to the former owner of Oyster Cree | ||||||||||
[9] | )Amounts related to certain real estate leases and railroad licenses effectively have indefinite payment periods. As a result, ComEd, PECO, BGE and DPL have excluded these payments from the remaining years as such amounts would not be meaningful. ComEd's, PECO’s, BGE’s and DPL's average annual obligation for these arrangements, included in each of the years 2019 - 2023, was $3 million, $5 million, $1 million and $1 million respectivel | ||||||||||
[10] | )The BGE column above includes minimum future lease payments associated with a 6-year lease for the Baltimore City conduit system that became effective during the fourth quarter of 2016. BGE's total commitments under the lease agreement are $26 million, $28 million, $28 million and $14 million related to years 2019 - 2022 , respectivel | ||||||||||
[11] | )The BGE column above includes minimum future lease payments associated with a 6-year lease for the Baltimore City conduit system that became effective during the fourth quarter of 2016. BGE's total commitments under the lease agreement are $26 million, $28 million, $28 million and $14 million related to years 2019 - 2022 , respectivel |
Commitments and Contingencies_3
Commitments and Contingencies Commitments and Contingencies - Schedule of Commercial Commitments (Details) $ in Millions | Dec. 31, 2018USD ($) | |
Guarantor Obligations [Line Items] | ||
Contractual Obligation | $ 3,507 | |
Contractual Obligation, Due in Next Fiscal Year | 2,728 | |
Contractual Obligation, Due in Second Year | 344 | |
Contractual Obligation, Due in Third Year | 41 | |
Contractual Obligation, Due in Fourth Year | 3 | |
Contractual Obligation, Due in Fifth Year | 3 | |
Contractual Obligation, Due after Fifth Year | 388 | |
Guarantee obligations maximum exposure | 61 | |
Exelon Generation Co L L C [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 2,900 | |
Contractual Obligation, Due in Next Fiscal Year | 2,581 | |
Contractual Obligation, Due in Second Year | 318 | |
Contractual Obligation, Due in Third Year | 1 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 0 | |
Commonwealth Edison Co [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 214 | |
Contractual Obligation, Due in Next Fiscal Year | 12 | |
Contractual Obligation, Due in Second Year | 0 | |
Contractual Obligation, Due in Third Year | 2 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 200 | |
PECO Energy Co [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 187 | |
Contractual Obligation, Due in Next Fiscal Year | 9 | |
Contractual Obligation, Due in Second Year | 0 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 178 | |
Baltimore Gas and Electric Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 20 | |
Contractual Obligation, Due in Next Fiscal Year | 5 | |
Contractual Obligation, Due in Second Year | 15 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 0 | |
Pepco Holdings LLC [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 73 | |
Contractual Obligation, Due in Next Fiscal Year | 44 | |
Contractual Obligation, Due in Second Year | 11 | |
Contractual Obligation, Due in Third Year | 2 | |
Contractual Obligation, Due in Fourth Year | 3 | |
Contractual Obligation, Due in Fifth Year | 3 | |
Contractual Obligation, Due after Fifth Year | 10 | |
Potomac Electric Power Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 49 | |
Contractual Obligation, Due in Next Fiscal Year | 34 | |
Contractual Obligation, Due in Second Year | 9 | |
Contractual Obligation, Due in Third Year | 1 | |
Contractual Obligation, Due in Fourth Year | 1 | |
Contractual Obligation, Due in Fifth Year | 1 | |
Contractual Obligation, Due after Fifth Year | 3 | |
Guarantee obligations maximum exposure | 19 | |
Delmarva Power & Light Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 15 | |
Contractual Obligation, Due in Next Fiscal Year | 6 | |
Contractual Obligation, Due in Second Year | 1 | |
Contractual Obligation, Due in Third Year | 1 | |
Contractual Obligation, Due in Fourth Year | 1 | |
Contractual Obligation, Due in Fifth Year | 1 | |
Contractual Obligation, Due after Fifth Year | 5 | |
Guarantee obligations maximum exposure | 26 | |
Atlantic City Electric Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 9 | |
Contractual Obligation, Due in Next Fiscal Year | 4 | |
Contractual Obligation, Due in Second Year | 1 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 1 | |
Contractual Obligation, Due in Fifth Year | 1 | |
Contractual Obligation, Due after Fifth Year | 2 | |
Guarantee obligations maximum exposure | 16 | |
Financial Standby Letter of Credit [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 1,703 | [1] |
Contractual Obligation, Due in Next Fiscal Year | 1,394 | [1] |
Contractual Obligation, Due in Second Year | 308 | [1] |
Contractual Obligation, Due in Third Year | 1 | [1] |
Contractual Obligation, Due in Fourth Year | 0 | [1] |
Contractual Obligation, Due in Fifth Year | 0 | [1] |
Contractual Obligation, Due after Fifth Year | 0 | [1] |
Financial Standby Letter of Credit [Member] | Exelon Generation Co L L C [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 1,680 | [2] |
Contractual Obligation, Due in Next Fiscal Year | 1,380 | [2] |
Contractual Obligation, Due in Second Year | 299 | [2] |
Contractual Obligation, Due in Third Year | 1 | [2] |
Contractual Obligation, Due in Fourth Year | 0 | [2] |
Contractual Obligation, Due in Fifth Year | 0 | [2] |
Contractual Obligation, Due after Fifth Year | 0 | [2] |
Financial Standby Letter of Credit [Member] | Commonwealth Edison Co [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 2 | [3] |
Contractual Obligation, Due in Next Fiscal Year | 2 | [3] |
Contractual Obligation, Due in Second Year | 0 | [3] |
Contractual Obligation, Due in Third Year | 0 | [3] |
Contractual Obligation, Due in Fourth Year | 0 | [3] |
Contractual Obligation, Due in Fifth Year | 0 | [3] |
Contractual Obligation, Due after Fifth Year | 0 | [3] |
Financial Standby Letter of Credit [Member] | Baltimore Gas and Electric Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 3 | [4] |
Contractual Obligation, Due in Next Fiscal Year | 2 | [4] |
Contractual Obligation, Due in Second Year | 1 | [4] |
Contractual Obligation, Due in Third Year | 0 | [4] |
Contractual Obligation, Due in Fourth Year | 0 | [4] |
Contractual Obligation, Due in Fifth Year | 0 | [4] |
Contractual Obligation, Due after Fifth Year | 0 | [4] |
Financial Standby Letter of Credit [Member] | Pepco Holdings LLC [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 8 | |
Contractual Obligation, Due in Next Fiscal Year | 0 | |
Contractual Obligation, Due in Second Year | 8 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 0 | |
Financial Standby Letter of Credit [Member] | Potomac Electric Power Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 8 | |
Contractual Obligation, Due in Next Fiscal Year | 0 | |
Contractual Obligation, Due in Second Year | 8 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 0 | |
Surety Bond [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 1,402 | [5] |
Contractual Obligation, Due in Next Fiscal Year | 1,331 | [5] |
Contractual Obligation, Due in Second Year | 33 | [5] |
Contractual Obligation, Due in Third Year | 38 | [5] |
Contractual Obligation, Due in Fourth Year | 0 | [5] |
Contractual Obligation, Due in Fifth Year | 0 | [5] |
Contractual Obligation, Due after Fifth Year | 0 | [5] |
Surety Bond [Member] | Exelon Generation Co L L C [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 1,220 | |
Contractual Obligation, Due in Next Fiscal Year | 1,201 | |
Contractual Obligation, Due in Second Year | 19 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 0 | |
Surety Bond [Member] | Commonwealth Edison Co [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 12 | [6] |
Contractual Obligation, Due in Next Fiscal Year | 10 | [6] |
Contractual Obligation, Due in Second Year | 0 | [6] |
Contractual Obligation, Due in Third Year | 2 | [6] |
Contractual Obligation, Due in Fourth Year | 0 | [6] |
Contractual Obligation, Due in Fifth Year | 0 | [6] |
Contractual Obligation, Due after Fifth Year | 0 | [6] |
Surety Bond [Member] | PECO Energy Co [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 9 | [7] |
Contractual Obligation, Due in Next Fiscal Year | 9 | [7] |
Contractual Obligation, Due in Second Year | 0 | [7] |
Contractual Obligation, Due in Third Year | 0 | [7] |
Contractual Obligation, Due in Fourth Year | 0 | [7] |
Contractual Obligation, Due in Fifth Year | 0 | [7] |
Contractual Obligation, Due after Fifth Year | 0 | [7] |
Surety Bond [Member] | Baltimore Gas and Electric Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 17 | [8] |
Contractual Obligation, Due in Next Fiscal Year | 3 | [8] |
Contractual Obligation, Due in Second Year | 14 | [8] |
Contractual Obligation, Due in Third Year | 0 | [8] |
Contractual Obligation, Due in Fourth Year | 0 | [8] |
Contractual Obligation, Due in Fifth Year | 0 | [8] |
Contractual Obligation, Due after Fifth Year | 0 | [8] |
Surety Bond [Member] | Pepco Holdings LLC [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 41 | |
Contractual Obligation, Due in Next Fiscal Year | 41 | |
Contractual Obligation, Due in Second Year | 0 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 0 | |
Surety Bond [Member] | Potomac Electric Power Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 33 | [9] |
Contractual Obligation, Due in Next Fiscal Year | 33 | [9] |
Contractual Obligation, Due in Second Year | 0 | [9] |
Contractual Obligation, Due in Third Year | 0 | [9] |
Contractual Obligation, Due in Fourth Year | 0 | [9] |
Contractual Obligation, Due in Fifth Year | 0 | [9] |
Contractual Obligation, Due after Fifth Year | 0 | [9] |
Surety Bond [Member] | Delmarva Power & Light Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 5 | [10] |
Contractual Obligation, Due in Next Fiscal Year | 5 | [10] |
Contractual Obligation, Due in Second Year | 0 | [10] |
Contractual Obligation, Due in Third Year | 0 | [10] |
Contractual Obligation, Due in Fourth Year | 0 | [10] |
Contractual Obligation, Due in Fifth Year | 0 | [10] |
Contractual Obligation, Due after Fifth Year | 0 | [10] |
Surety Bond [Member] | Atlantic City Electric Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 3 | |
Contractual Obligation, Due in Next Fiscal Year | 3 | |
Contractual Obligation, Due in Second Year | 0 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 0 | |
Trust Preferred Securities [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 378 | |
Contractual Obligation, Due in Next Fiscal Year | 0 | |
Contractual Obligation, Due in Second Year | 0 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 378 | |
Trust Preferred Securities [Member] | Commonwealth Edison Co [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 200 | |
Contractual Obligation, Due in Next Fiscal Year | 0 | |
Contractual Obligation, Due in Second Year | 0 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 200 | |
Trust Preferred Securities [Member] | PECO Energy Co [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 178 | |
Contractual Obligation, Due in Next Fiscal Year | 0 | |
Contractual Obligation, Due in Second Year | 0 | |
Contractual Obligation, Due in Third Year | 0 | |
Contractual Obligation, Due in Fourth Year | 0 | |
Contractual Obligation, Due in Fifth Year | 0 | |
Contractual Obligation, Due after Fifth Year | 178 | |
GuaranteedLeaseResidualValues [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 24 | [11] |
Contractual Obligation, Due in Next Fiscal Year | 3 | [11] |
Contractual Obligation, Due in Second Year | 3 | [11] |
Contractual Obligation, Due in Third Year | 2 | [11] |
Contractual Obligation, Due in Fourth Year | 3 | [11] |
Contractual Obligation, Due in Fifth Year | 3 | [11] |
Contractual Obligation, Due after Fifth Year | 10 | [11] |
GuaranteedLeaseResidualValues [Member] | Pepco Holdings LLC [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 24 | [12] |
Contractual Obligation, Due in Next Fiscal Year | 3 | [12] |
Contractual Obligation, Due in Second Year | 3 | [12] |
Contractual Obligation, Due in Third Year | 2 | [12] |
Contractual Obligation, Due in Fourth Year | 3 | [12] |
Contractual Obligation, Due in Fifth Year | 3 | [12] |
Contractual Obligation, Due after Fifth Year | 10 | [12] |
GuaranteedLeaseResidualValues [Member] | Potomac Electric Power Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 8 | [13] |
Contractual Obligation, Due in Next Fiscal Year | 1 | [13] |
Contractual Obligation, Due in Second Year | 1 | [13] |
Contractual Obligation, Due in Third Year | 1 | [13] |
Contractual Obligation, Due in Fourth Year | 1 | [13] |
Contractual Obligation, Due in Fifth Year | 1 | [13] |
Contractual Obligation, Due after Fifth Year | 3 | [13] |
GuaranteedLeaseResidualValues [Member] | Delmarva Power & Light Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 10 | [14] |
Contractual Obligation, Due in Next Fiscal Year | 1 | [14] |
Contractual Obligation, Due in Second Year | 1 | [14] |
Contractual Obligation, Due in Third Year | 1 | [14] |
Contractual Obligation, Due in Fourth Year | 1 | [14] |
Contractual Obligation, Due in Fifth Year | 1 | [14] |
Contractual Obligation, Due after Fifth Year | 5 | [14] |
GuaranteedLeaseResidualValues [Member] | Atlantic City Electric Company [Member] | ||
Guarantor Obligations [Line Items] | ||
Contractual Obligation | 6 | [15] |
Contractual Obligation, Due in Next Fiscal Year | 1 | [15] |
Contractual Obligation, Due in Second Year | 1 | [15] |
Contractual Obligation, Due in Third Year | 0 | [15] |
Contractual Obligation, Due in Fourth Year | 1 | [15] |
Contractual Obligation, Due in Fifth Year | 1 | [15] |
Contractual Obligation, Due after Fifth Year | $ 2 | [15] |
[1] | _ | |
[2] | _ | |
[3] | _ | |
[4] | _ | |
[5] | Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. | |
[6] | Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bond | |
[7] | )Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bond | |
[8] | Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bond | |
[9] | (a)Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bond | |
[10] | )Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bond | |
[11] | Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $61 million, $19 million of which is a guarantee by Pepco, $26 million by DPL and $16 million by ACE. The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and PHI believes the likelihood of payments being required under the guarantees is remote. | |
[12] | (a)Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds.(b)Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $61 million. The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and PHI believes the likelihood of payments being required under the guarantees is remot | |
[13] | Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $19 million. The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and Pepco believes the likelihood of payments being required under the guarantees is remot | |
[14] | )Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $26 million. The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and DPL believes the likelihood of payments being required under the guarantees is remot | |
[15] | )Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds.(b)Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The maximum lease term associated with these assets ranges from 3 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $16 million. The minimum lease term associated with these assets ranges from 1 to 4 years. Historically, payments under the guarantees have not been made and ACE believes the likelihood of payments being required under the guarantees is remot |
Commitments and Contingencies_4
Commitments and Contingencies Commitments and Contingencies - Schedule of Minimum Future Operating Lease Payments (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Nov. 30, 2016 | ||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
2,018 | [1],[2] | $ 140 | ||
2,019 | [1],[2] | 149 | ||
2,020 | [1],[2] | 143 | ||
2,021 | [1],[2] | 126 | ||
2,022 | [1],[2] | 97 | ||
Remaining Years | [1],[2] | 723 | ||
Total minimum future lease payments | [1],[2] | 1,378 | ||
Exelon Generation Co L L C [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
2,018 | [1],[2] | 33 | ||
2,019 | [1],[2] | 46 | ||
2,020 | [1],[2] | 46 | ||
2,021 | [1],[2] | 47 | ||
2,022 | [1],[2] | 46 | ||
Remaining Years | [1],[2] | 545 | ||
Total minimum future lease payments | [1],[2] | 763 | ||
Commonwealth Edison Co [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
2,018 | [2],[3] | 7 | ||
2,019 | [2],[3] | 5 | ||
2,020 | [2],[3] | 4 | ||
2,021 | [2],[3] | 4 | ||
2,022 | [2],[3] | 3 | ||
Remaining Years | [2],[3] | 0 | ||
Total minimum future lease payments | [2],[3] | 23 | ||
Commonwealth Edison Co [Member] | Real Estate Leases and Railroad Licenses [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
Total minimum future lease payments | 3 | |||
PECO Energy Co [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
2,018 | [2],[3] | 5 | ||
2,019 | [2],[3] | 5 | ||
2,020 | [2],[3] | 5 | ||
2,021 | [2],[3] | 5 | ||
2,022 | [2],[3] | 5 | ||
Remaining Years | [2],[3] | 0 | ||
Total minimum future lease payments | [2],[3] | 25 | ||
PECO Energy Co [Member] | Real Estate Leases and Railroad Licenses [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
Total minimum future lease payments | 5 | |||
Baltimore Gas and Electric Company [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
2,018 | 35 | [2],[3],[4],[5] | $ 26 | |
2,019 | 35 | [2],[3],[4],[5] | 28 | |
2,020 | 33 | [2],[3],[4],[5] | 28 | |
2,021 | 18 | [2],[3],[4],[5] | $ 14 | |
2,022 | [2],[3],[4],[5] | 3 | ||
Remaining Years | [2],[3],[4],[5] | 19 | ||
Total minimum future lease payments | [2],[3],[4],[5] | 143 | ||
Baltimore Gas and Electric Company [Member] | Real Estate Leases and Railroad Licenses [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
Total minimum future lease payments | 1 | |||
Pepco Holdings LLC [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
2,018 | [2] | 48 | ||
2,019 | [2] | 46 | ||
2,020 | [2] | 43 | ||
2,021 | [2] | 42 | ||
2,022 | [2] | 39 | ||
Remaining Years | [2] | 159 | ||
Total minimum future lease payments | [2] | 377 | ||
Potomac Electric Power Company [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
2,018 | [2] | 11 | ||
2,019 | [2] | 10 | ||
2,020 | [2] | 9 | ||
2,021 | [2] | 8 | ||
2,022 | [2] | 8 | ||
Remaining Years | [2] | 40 | ||
Total minimum future lease payments | [2] | 86 | ||
Delmarva Power & Light Company [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
2,018 | [2],[3] | 14 | ||
2,019 | [2],[3] | 13 | ||
2,020 | [2],[3] | 12 | ||
2,021 | [2],[3] | 12 | ||
2,022 | [2],[3] | 10 | ||
Remaining Years | [2],[3] | 35 | ||
Total minimum future lease payments | [2],[3] | 96 | ||
Delmarva Power & Light Company [Member] | Real Estate Leases and Railroad Licenses [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
Total minimum future lease payments | 1 | |||
Atlantic City Electric Company [Member] | ||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||
2,018 | [2] | 7 | ||
2,019 | [2] | 6 | ||
2,020 | [2] | 5 | ||
2,021 | [2] | 5 | ||
2,022 | [2] | 4 | ||
Remaining Years | [2] | 5 | ||
Total minimum future lease payments | [2] | $ 32 | ||
[1] | )Excludes Generation’s contingent operating lease payments associated with contracted generation agreement | |||
[2] | )Includes amounts related to shared use land arrangement | |||
[3] | )Amounts related to certain real estate leases and railroad licenses effectively have indefinite payment periods. As a result, ComEd, PECO, BGE and DPL have excluded these payments from the remaining years as such amounts would not be meaningful. ComEd's, PECO’s, BGE’s and DPL's average annual obligation for these arrangements, included in each of the years 2019 - 2023, was $3 million, $5 million, $1 million and $1 million respectivel | |||
[4] | )The BGE column above includes minimum future lease payments associated with a 6-year lease for the Baltimore City conduit system that became effective during the fourth quarter of 2016. BGE's total commitments under the lease agreement are $26 million, $28 million, $28 million and $14 million related to years 2019 - 2022 , respectivel | |||
[5] | )The BGE column above includes minimum future lease payments associated with a 6-year lease for the Baltimore City conduit system that became effective during the fourth quarter of 2016. BGE's total commitments under the lease agreement are $26 million, $28 million, $28 million and $14 million related to years 2019 - 2022 , respectivel |
Commitments and Contingencies_5
Commitments and Contingencies Commitments and Contingencies - Schedule of Future Rental Expense under Operating Leases (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Operating Leases Future Minimum Payments Due [Line Items] | ||||||
Lease and rental expense | $ 670 | $ 709 | $ 777 | |||
Exelon Generation Co L L C [Member] | ||||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||||
Lease and rental expense | [1] | 558 | 578 | 667 | ||
Long Term Contract For Purchase Of Electric Power Capacity | $ 604 | 493 | 508 | 604 | ||
Commonwealth Edison Co [Member] | ||||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||||
Lease and rental expense | 7 | 9 | 15 | |||
PECO Energy Co [Member] | ||||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||||
Lease and rental expense | 10 | 9 | 7 | |||
Baltimore Gas and Electric Company [Member] | ||||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||||
Lease and rental expense | 35 | 32 | 22 | |||
Pepco Holdings LLC [Member] | Successor [Member] | ||||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||||
Lease and rental expense | $ 49 | 48 | 63 | |||
Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||||
Lease and rental expense | $ 12 | |||||
Potomac Electric Power Company [Member] | ||||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||||
Lease and rental expense | 10 | 11 | 8 | |||
Delmarva Power & Light Company [Member] | ||||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||||
Lease and rental expense | 13 | 16 | 15 | |||
Atlantic City Electric Company [Member] | ||||||
Operating Leases Future Minimum Payments Due [Line Items] | ||||||
Lease and rental expense | $ 8 | $ 14 | $ 13 | |||
[1] | )Includes contingent operating lease payments associated with contracted generation agreements that are not included in the minimum future operating lease payments table above. Payments made under Generation’s contracted generation lease agreements totaled $493 million, $508 million and $604 million during 2018, 2017 and 2016, respectively. Excludes contract amortization associated with purchase accounting and contract acquisition |
Commitments and Contingencies_6
Commitments and Contingencies Commitments and Contingencies - Settlement Agreements (Details) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | ||
Dec. 31, 2014 | Dec. 31, 2018 | Dec. 31, 2017 | ||
Guarantor Obligations [Line Items] | ||||
Nontrade Receivables, Current | [1] | $ 124 | $ 94 | |
Nontrade Receivables, Noncurrent | [2] | 15 | 15 | |
Accounts Payable, Other, Current | [1],[3] | (17) | $ (11) | |
Exelon Generation Co L L C [Member] | ||||
Guarantor Obligations [Line Items] | ||||
Spent Nuclear Fuel Storage Reimbursement | [4] | 1,274 | ||
Spent Nuclear Fuel Storage Reimbursement Net Co Owners | [4],[5] | $ 1,100 | ||
Exelon Generation Co L L C [Member] | Department of Energy [Member] | ||||
Guarantor Obligations [Line Items] | ||||
Spent Nuclear Fuel Storage Reimbursement | $ 53 | |||
Spent Nuclear Fuel Storage Reimbursement Net Co Owners | $ 49 | |||
[1] | )Recorded in Accounts receivable, other. | |||
[2] | )Recorded in Deferred debits and other assets, oth | |||
[3] | )Non-CENG amounts owed to co-owners are recorded in Accounts receivable, other. CENG amounts owed to co-owners are recorded in Accounts payable. Represents amounts owed to the co-owners of Peach Bottom, Quad Cities, and Nine Mile Point Unit 2 generating facilities | |||
[4] | )Includes $53 and $49, respectively, for amounts received since April 1, 2014, for costs incurred under the CENG DOE Settlement Agreements prior to the consolidation of CEN | |||
[5] | )Total after considering amounts due to co-owners of certain nuclear stations and to the former owner of Oyster Cree |
Commitments and Contingencies_7
Commitments and Contingencies Commitments and Contingencies - Schedule of Environmental Liabilities (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 |
Total Accrual For Environmental Loss Contingencies [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | $ 496 | $ 466 |
Accrual For MGP Investigation And Remediation [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 356 | 315 |
Exelon Generation Co L L C [Member] | Total Accrual For Environmental Loss Contingencies [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 108 | 117 |
Exelon Generation Co L L C [Member] | Accrual For MGP Investigation And Remediation [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 0 | 0 |
Commonwealth Edison Co [Member] | Total Accrual For Environmental Loss Contingencies [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 329 | 285 |
Commonwealth Edison Co [Member] | Accrual For MGP Investigation And Remediation [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 327 | 283 |
PECO Energy Co [Member] | Total Accrual For Environmental Loss Contingencies [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 27 | 30 |
PECO Energy Co [Member] | Accrual For MGP Investigation And Remediation [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 25 | 28 |
Baltimore Gas and Electric Company [Member] | Total Accrual For Environmental Loss Contingencies [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 5 | 5 |
Baltimore Gas and Electric Company [Member] | Accrual For MGP Investigation And Remediation [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 4 | 4 |
Pepco Holdings LLC [Member] | Total Accrual For Environmental Loss Contingencies [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 27 | 29 |
Pepco Holdings LLC [Member] | Accrual For MGP Investigation And Remediation [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 0 | 0 |
Potomac Electric Power Company [Member] | Total Accrual For Environmental Loss Contingencies [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 25 | 27 |
Potomac Electric Power Company [Member] | Accrual For MGP Investigation And Remediation [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 0 | 0 |
Delmarva Power & Light Company [Member] | Total Accrual For Environmental Loss Contingencies [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 1 | 1 |
Delmarva Power & Light Company [Member] | Accrual For MGP Investigation And Remediation [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 0 | 0 |
Atlantic City Electric Company [Member] | Total Accrual For Environmental Loss Contingencies [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | 1 | 1 |
Atlantic City Electric Company [Member] | Accrual For MGP Investigation And Remediation [Member] | ||
Loss Contingencies [Line Items] | ||
Accrual for Environmental Loss Contingencies, Gross | $ 0 | $ 0 |
Supplemental Financial Inform_3
Supplemental Financial Information Supplemental Financial Information - Summary of Taxes other than income (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | $ 919 | $ 898 | $ 753 | ||
Property | 557 | 545 | 483 | |||
Payroll | 247 | 230 | 226 | |||
Other | 60 | 58 | 114 | |||
Total taxes other than income | 1,783 | 1,731 | 1,576 | |||
Exelon Generation Co L L C [Member] | ||||||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | 114 | 126 | 122 | ||
Property | 273 | 269 | 246 | |||
Payroll | 130 | 121 | 117 | |||
Other | 39 | 39 | 21 | |||
Total taxes other than income | 556 | 555 | 506 | |||
Commonwealth Edison Co [Member] | ||||||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | 243 | 240 | 242 | ||
Property | 30 | 28 | 27 | |||
Payroll | 27 | 26 | 28 | |||
Other | 11 | 2 | (4) | |||
Total taxes other than income | 311 | 296 | 293 | |||
PECO Energy Co [Member] | ||||||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | 131 | 125 | 136 | ||
Property | 15 | 14 | 13 | |||
Payroll | 16 | 15 | 15 | |||
Other | 1 | 0 | 0 | |||
Total taxes other than income | 163 | 154 | 164 | |||
Baltimore Gas and Electric Company [Member] | ||||||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | 94 | 89 | 85 | ||
Property | 143 | 132 | 123 | |||
Payroll | 17 | 15 | 17 | |||
Other | 0 | 4 | 4 | |||
Total taxes other than income | 254 | 240 | 229 | |||
Pepco Holdings LLC [Member] | ||||||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | 337 | 318 | |||
Property | 94 | 101 | ||||
Payroll | 24 | 26 | ||||
Other | 0 | 7 | ||||
Total taxes other than income | 455 | 452 | ||||
Pepco Holdings LLC [Member] | Successor [Member] | ||||||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | $ 253 | ||||
Property | 73 | |||||
Payroll | 23 | |||||
Other | 5 | |||||
Total taxes other than income | $ 354 | |||||
Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | $ 78 | ||||
Property | 18 | |||||
Payroll | 8 | |||||
Other | 1 | |||||
Total taxes other than income | $ 105 | |||||
Potomac Electric Power Company [Member] | ||||||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | 316 | 300 | 312 | ||
Property | 58 | 62 | 53 | |||
Payroll | 5 | 6 | 8 | |||
Other | 0 | 3 | 4 | |||
Total taxes other than income | 379 | 371 | 377 | |||
Delmarva Power & Light Company [Member] | ||||||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | 21 | 18 | 18 | ||
Property | 32 | 32 | 31 | |||
Payroll | 3 | 4 | 5 | |||
Other | 0 | 3 | 1 | |||
Total taxes other than income | 56 | 57 | 55 | |||
Atlantic City Electric Company [Member] | ||||||
Supplemental Statement of Operations Information [Line Items] | ||||||
Utility | [1] | 0 | 0 | 0 | ||
Property | 3 | 3 | 3 | |||
Payroll | 2 | 2 | 3 | |||
Other | 0 | 1 | 1 | |||
Total taxes other than income | $ 5 | $ 6 | $ 7 | |||
[1] | Generation’s utility tax represents gross receipts tax related to its retail operations and ComEd’s, PECO’s, BGE’s, Pepco's, DPL's and ACE's utility taxes represent municipal and state utility taxes and gross receipts taxes related to their operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. |
Supplemental Financial Inform_4
Supplemental Financial Information Supplemental Financial Information - Summary of Other Income (Expense) (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Decommissioning-Related Activities [Abstract] | ||||||
Net realized income on NDT funds - Regulatory agreement units | [1] | $ 506 | $ 488 | $ 237 | ||
Net realized income on NDT funds - Non-regulatory agreement units | [1] | 302 | 209 | 126 | ||
Net unrealized gains (losses) on NDT funds - Regulatory agreement units | (715) | 455 | 216 | |||
Net unrealized gains (losses) on NDT funds - Non-regulatory agreement | (483) | 521 | 194 | |||
Net unrealized income (losses) on pledged assets | (8) | (10) | (1) | |||
Regulatory offset to NDT fund-related activities | [2] | 171 | (724) | (372) | ||
Total decommissioning-related activities | (227) | 939 | 400 | |||
Investment income (loss) | 43 | 8 | 17 | |||
Long-term lease income | 4 | |||||
Interest income (expense) related to uncertain income tax positions | 5 | 3 | 13 | |||
Benefit (penalty) related to uncertain income tax positions | [3] | 2 | (106) | |||
AFUDC—Equity | 69 | 73 | 64 | |||
Non-service net periodic benefit cost | (47) | (109) | (116) | |||
Loss on debt extinguishment | (3) | |||||
Other | 45 | 31 | 24 | |||
Other, net | (112) | 947 | 297 | |||
Exelon Generation Co L L C [Member] | ||||||
Decommissioning-Related Activities [Abstract] | ||||||
Net realized income on NDT funds - Regulatory agreement units | [1] | 506 | 488 | 237 | ||
Net realized income on NDT funds - Non-regulatory agreement units | [1] | 302 | 209 | 126 | ||
Net unrealized gains (losses) on NDT funds - Regulatory agreement units | (715) | 455 | 216 | |||
Net unrealized gains (losses) on NDT funds - Non-regulatory agreement | (483) | 521 | 194 | |||
Net unrealized income (losses) on pledged assets | (8) | (10) | (1) | |||
Regulatory offset to NDT fund-related activities | [2] | 171 | (724) | (372) | ||
Total decommissioning-related activities | (227) | 939 | 400 | |||
Investment income (loss) | 32 | 6 | 8 | |||
Long-term lease income | 0 | |||||
Interest income (expense) related to uncertain income tax positions | 1 | (1) | 0 | |||
Benefit (penalty) related to uncertain income tax positions | [3] | 0 | 0 | |||
AFUDC—Equity | 0 | 0 | 0 | |||
Loss on debt extinguishment | (2) | |||||
Other | 16 | 4 | (5) | |||
Other, net | (178) | 948 | 401 | |||
Commonwealth Edison Co [Member] | ||||||
Decommissioning-Related Activities [Abstract] | ||||||
Investment income (loss) | 0 | 0 | 0 | |||
Long-term lease income | 0 | |||||
Interest income (expense) related to uncertain income tax positions | 0 | 0 | 0 | |||
Benefit (penalty) related to uncertain income tax positions | [3] | 0 | (86) | |||
AFUDC—Equity | 19 | 12 | 14 | |||
Loss on debt extinguishment | 0 | |||||
Other | 14 | 10 | 7 | |||
Other, net | 33 | 22 | (65) | |||
PECO Energy Co [Member] | ||||||
Decommissioning-Related Activities [Abstract] | ||||||
Investment income (loss) | 1 | 0 | (1) | |||
Long-term lease income | 0 | |||||
Interest income (expense) related to uncertain income tax positions | 0 | 0 | 0 | |||
Benefit (penalty) related to uncertain income tax positions | [3] | 0 | 0 | |||
AFUDC—Equity | 7 | 9 | 8 | |||
Loss on debt extinguishment | 0 | |||||
Other | 0 | 0 | 1 | |||
Other, net | 8 | 9 | 8 | |||
Baltimore Gas and Electric Company [Member] | ||||||
Decommissioning-Related Activities [Abstract] | ||||||
Investment income (loss) | 1 | 0 | 2 | |||
Long-term lease income | 0 | |||||
Interest income (expense) related to uncertain income tax positions | 0 | 0 | 0 | |||
Benefit (penalty) related to uncertain income tax positions | [3] | 0 | 0 | |||
AFUDC—Equity | 18 | 16 | 19 | |||
Loss on debt extinguishment | 0 | |||||
Other | 0 | 0 | 0 | |||
Other, net | 19 | 16 | 21 | |||
Pepco Holdings LLC [Member] | ||||||
Decommissioning-Related Activities [Abstract] | ||||||
Investment income (loss) | 4 | 2 | ||||
Interest income (expense) related to uncertain income tax positions | 0 | 0 | ||||
Benefit (penalty) related to uncertain income tax positions | [3] | 0 | ||||
AFUDC—Equity | 25 | 36 | ||||
Other | 14 | 16 | ||||
Other, net | 43 | 54 | ||||
Pepco Holdings LLC [Member] | Successor [Member] | ||||||
Decommissioning-Related Activities [Abstract] | ||||||
Investment income (loss) | $ 1 | |||||
Long-term lease income | 0 | |||||
Interest income (expense) related to uncertain income tax positions | (1) | |||||
Benefit (penalty) related to uncertain income tax positions | [3] | 0 | ||||
AFUDC—Equity | 23 | |||||
Loss on debt extinguishment | 0 | |||||
Other | 21 | |||||
Other, net | $ 44 | |||||
Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||
Decommissioning-Related Activities [Abstract] | ||||||
Investment income (loss) | $ 0 | |||||
Long-term lease income | 0 | |||||
Interest income (expense) related to uncertain income tax positions | 0 | |||||
Benefit (penalty) related to uncertain income tax positions | [3] | 0 | ||||
AFUDC—Equity | 7 | |||||
Loss on debt extinguishment | 0 | |||||
Other | (11) | |||||
Other, net | $ (4) | |||||
Potomac Electric Power Company [Member] | ||||||
Decommissioning-Related Activities [Abstract] | ||||||
Investment income (loss) | 2 | 1 | 1 | |||
Long-term lease income | 0 | |||||
Interest income (expense) related to uncertain income tax positions | 0 | 0 | 1 | |||
Benefit (penalty) related to uncertain income tax positions | [3] | 0 | 0 | |||
AFUDC—Equity | 22 | 23 | 19 | |||
Loss on debt extinguishment | 0 | |||||
Other | 7 | 8 | 15 | |||
Other, net | 31 | 32 | 36 | |||
Delmarva Power & Light Company [Member] | ||||||
Decommissioning-Related Activities [Abstract] | ||||||
Investment income (loss) | 1 | 0 | 0 | |||
Long-term lease income | 0 | |||||
Interest income (expense) related to uncertain income tax positions | 0 | 0 | 0 | |||
Benefit (penalty) related to uncertain income tax positions | [3] | 0 | 0 | |||
AFUDC—Equity | 2 | 7 | 5 | |||
Loss on debt extinguishment | 0 | |||||
Other | 7 | 7 | 8 | |||
Other, net | 10 | 14 | 13 | |||
Atlantic City Electric Company [Member] | ||||||
Decommissioning-Related Activities [Abstract] | ||||||
Investment income (loss) | 0 | 0 | 1 | |||
Long-term lease income | 0 | |||||
Interest income (expense) related to uncertain income tax positions | 0 | 0 | 0 | |||
Benefit (penalty) related to uncertain income tax positions | [3] | 0 | 0 | |||
AFUDC—Equity | 1 | 6 | 6 | |||
Loss on debt extinguishment | 0 | |||||
Other | 1 | 1 | 2 | |||
Other, net | $ 2 | $ 7 | $ 9 | |||
[1] | Includes investment income and realized gains and losses on sales of investments within the NDT funds. | |||||
[2] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246MTE0OEY2QkJBNTBGNUFBQ0IwMkE4RTI0QzY3MTNDRUEM} | |||||
[3] | See Note 14—Income Taxes for additional information on the penalty related to the Tax Court’s decision on Exelon’s like-kind exchange tax position. |
Supplemental Financial Inform_5
Supplemental Financial Information Supplemental Financial Information - Supplemental Cash Flow Information (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||||||||
Dec. 31, 2018 | Sep. 30, 2018 | Mar. 23, 2016 | Sep. 30, 2017 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | $ 3,740 | $ 3,293 | $ 3,477 | |||||||||
Amortization of Regulatory Asset | 555 | 478 | 407 | |||||||||
Amortization of Intangible Assets | (109) | (237) | (336) | |||||||||
Amortization of Nuclear Fuel Lease | [1] | 1,115 | 1,096 | 1,159 | ||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 489 | 468 | 446 | ||||||||
Total depreciation, amortization and accretion | 5,971 | 5,427 | 5,576 | |||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 1,421 | 2,430 | 1,340 | |||||||||
Income taxes (net of refunds) | 95 | 540 | (441) | |||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 583 | 643 | 619 | |||||||||
Gain (loss) on equity method investments | 28 | 32 | 24 | |||||||||
Provision for uncollectible accounts | 159 | 125 | 155 | |||||||||
Provision for excess and obsolete inventory | 24 | 56 | 12 | |||||||||
Stock-based compensation costs | 75 | 88 | 111 | |||||||||
Other decommissioning related-activity | (2) | [3] | (313) | [4] | (384) | [5] | ||||||
Energy-related options | 10 | [6] | 7 | [7] | (11) | [8] | ||||||
Amortization of regulatory asset related to debt costs | 8 | 9 | 9 | |||||||||
Amortization of rate stabilization deferral | 14 | (10) | 76 | |||||||||
Amortization of debt fair value adjustment | (15) | (18) | (11) | |||||||||
Merger-related commitments | 0 | [9] | 0 | [10] | 558 | [11],[12] | ||||||
Severance costs | 35 | 35 | 99 | |||||||||
Amortization of debt costs | 36 | 64 | 35 | |||||||||
Discrete impacts from EIMA and FEJA | 28 | [13] | (52) | [14] | 8 | [15] | ||||||
Vacation accrual adjustment | [16] | 68 | ||||||||||
Long-term incentive plan | 140 | 109 | 70 | |||||||||
Change in environmental liabilities | 44 | |||||||||||
Lower of cost or market inventory adjustment | 37 | |||||||||||
Baltimore City conduit lease settlement | (28) | |||||||||||
Cash Working Capital order | (13) | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 20 | 2 | ||||||||||
Other | (19) | (30) | (35) | |||||||||
Total other non-cash operating activities | 1,124 | 721 | 1,333 | |||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | (69) | 42 | (128) | |||||||||
Change in PPE related to ARO update | $ (107) | $ 191 | (107) | 29 | 191 | |||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 16 | 95 | ||||||||||
Noncash or Part Noncash Divestiture, Amount of Consideration Received | [12] | 37 | ||||||||||
Dividends on stock compensation | 6 | 7 | 6 | |||||||||
Acquisition of land | 3 | |||||||||||
Assumption of member purchase liability | 154 | 208 | 6,923 | |||||||||
Dissolution of financing trust due to long-term debt retirement | 8 | |||||||||||
Fair value adjustment of long-term debt due to retirement | (5) | |||||||||||
Allowance for Doubtful Accounts Receivable, Write-offs | 5 | |||||||||||
Fitzpatrick [Member] | ||||||||||||
Non-cash investing and financing activities: | ||||||||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | [17] | (54) | ||||||||||
Exelon Generation Co L L C [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | 1,748 | 1,409 | 1,835 | |||||||||
Amortization of Regulatory Asset | 0 | 0 | 0 | |||||||||
Amortization of Intangible Assets | 63 | 83 | 79 | |||||||||
Amortization of Nuclear Fuel Lease | [1] | 1,115 | 1,096 | 1,159 | ||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 489 | 468 | 446 | ||||||||
Total depreciation, amortization and accretion | 3,415 | 3,056 | 3,519 | |||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 369 | 391 | 339 | |||||||||
Income taxes (net of refunds) | 746 | 337 | 435 | |||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 204 | 227 | 218 | |||||||||
Gain (loss) on equity method investments | 30 | 33 | 25 | |||||||||
Provision for uncollectible accounts | 48 | 38 | 19 | |||||||||
Provision for excess and obsolete inventory | 20 | 51 | 6 | |||||||||
Other decommissioning related-activity | (2) | [3] | (313) | [4] | (384) | [5] | ||||||
Energy-related options | 10 | [6] | 7 | [7] | (11) | [8] | ||||||
Amortization of regulatory asset related to debt costs | 0 | 0 | 0 | |||||||||
Amortization of rate stabilization deferral | 0 | 0 | 0 | |||||||||
Amortization of debt fair value adjustment | (12) | (12) | (11) | |||||||||
Merger-related commitments | 0 | [9] | 0 | [10] | 53 | [11],[12] | ||||||
Severance costs | 9 | 31 | 22 | |||||||||
Amortization of debt costs | 14 | 37 | 17 | |||||||||
Vacation accrual adjustment | [16] | 35 | ||||||||||
Change in environmental liabilities | 44 | |||||||||||
Lower of cost or market inventory adjustment | 36 | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 203 | $ 84 | $ 138 | 0 | 0 | |||||||
Other | (23) | 4 | 25 | |||||||||
Total other non-cash operating activities | 298 | 112 | 15 | |||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | (199) | 73 | 50 | |||||||||
Change in PPE related to ARO update | (130) | 191 | (130) | 29 | 191 | |||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 16 | 95 | ||||||||||
Noncash or Part Noncash Divestiture, Amount of Consideration Received | [12] | 37 | ||||||||||
Acquisition of land | 0 | |||||||||||
Assumption of member purchase liability | 154 | 208 | 293 | |||||||||
Fair value of pension and OPEB obligation transferred in connection with FitzPatrick | 33 | |||||||||||
Exelon Generation Co L L C [Member] | noncash member [Member] | ||||||||||||
Non-cash investing and financing activities: | ||||||||||||
Fair value of net assets contributed (distributed) in connection with the PHI merger, net of cash | 119 | |||||||||||
Exelon Generation Co L L C [Member] | Fitzpatrick [Member] | ||||||||||||
Non-cash investing and financing activities: | ||||||||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | [17] | (54) | ||||||||||
Commonwealth Edison Co [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | 820 | 777 | 708 | |||||||||
Amortization of Regulatory Asset | 120 | 73 | 67 | |||||||||
Amortization of Intangible Assets | 7 | 7 | 7 | |||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 0 | 0 | 0 | ||||||||
Total depreciation, amortization and accretion | 940 | 850 | 775 | |||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 332 | 307 | 298 | |||||||||
Income taxes (net of refunds) | (153) | 83 | (444) | |||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 177 | 176 | 166 | |||||||||
Gain (loss) on equity method investments | 0 | 0 | 0 | |||||||||
Provision for uncollectible accounts | 40 | 34 | 41 | |||||||||
Provision for excess and obsolete inventory | 3 | 3 | 4 | |||||||||
Amortization of regulatory asset related to debt costs | 3 | 4 | 4 | |||||||||
Amortization of rate stabilization deferral | 0 | 0 | 0 | |||||||||
Amortization of debt fair value adjustment | 0 | 0 | 0 | |||||||||
Merger-related commitments | 0 | [9] | 0 | [10] | 0 | [11],[12] | ||||||
Severance costs | 0 | 0 | 0 | |||||||||
Amortization of debt costs | 5 | 5 | 4 | |||||||||
Discrete impacts from EIMA and FEJA | 28 | [13] | (52) | [14] | 8 | [15] | ||||||
Vacation accrual adjustment | [16] | 12 | ||||||||||
Change in environmental liabilities | 0 | |||||||||||
Lower of cost or market inventory adjustment | 0 | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | ||||||||||
Other | (14) | 6 | (12) | |||||||||
Total other non-cash operating activities | 242 | 164 | 215 | |||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | 11 | (61) | (91) | |||||||||
Change in PPE related to ARO update | 7 | 0 | 7 | 0 | 0 | |||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 0 | 0 | ||||||||||
Contribution of Property | 21 | [18] | 158 | [19] | ||||||||
Acquisition of land | 0 | |||||||||||
PECO Energy Co [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | 274 | 261 | 244 | |||||||||
Amortization of Regulatory Asset | 27 | 25 | 26 | |||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 0 | 0 | 0 | ||||||||
Total depreciation, amortization and accretion | 301 | 286 | 270 | |||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 125 | 103 | 104 | |||||||||
Income taxes (net of refunds) | (2) | 47 | 64 | |||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 18 | 29 | 33 | |||||||||
Gain (loss) on equity method investments | 0 | 0 | 0 | |||||||||
Provision for uncollectible accounts | 33 | 26 | 30 | |||||||||
Provision for excess and obsolete inventory | 0 | 0 | 0 | |||||||||
Amortization of regulatory asset related to debt costs | 1 | 1 | 1 | |||||||||
Amortization of rate stabilization deferral | 0 | 0 | 0 | |||||||||
Amortization of debt fair value adjustment | 0 | 0 | 0 | |||||||||
Merger-related commitments | 0 | [9] | 0 | [10] | 0 | [11],[12] | ||||||
Severance costs | 0 | 0 | 0 | |||||||||
Amortization of debt costs | 2 | 2 | 3 | |||||||||
Vacation accrual adjustment | [16] | 0 | ||||||||||
Change in environmental liabilities | 0 | |||||||||||
Lower of cost or market inventory adjustment | 1 | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | ||||||||||
Other | (3) | (4) | (3) | |||||||||
Total other non-cash operating activities | 51 | 54 | 65 | |||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | (12) | 22 | (11) | |||||||||
Change in PPE related to ARO update | 0 | 0 | 0 | 0 | 0 | |||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 0 | 0 | ||||||||||
Acquisition of land | 0 | |||||||||||
Baltimore Gas and Electric Company [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | 335 | 312 | 299 | |||||||||
Amortization of Regulatory Asset | 148 | 161 | 124 | |||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 0 | 0 | 0 | ||||||||
Total depreciation, amortization and accretion | 483 | 473 | 423 | |||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 94 | 96 | 92 | |||||||||
Income taxes (net of refunds) | 14 | (2) | 31 | |||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 59 | 62 | 67 | |||||||||
Gain (loss) on equity method investments | 0 | 0 | 0 | |||||||||
Provision for uncollectible accounts | 10 | 8 | 1 | |||||||||
Provision for excess and obsolete inventory | 0 | 0 | 0 | |||||||||
Amortization of regulatory asset related to debt costs | 0 | 0 | 0 | |||||||||
Amortization of rate stabilization deferral | 0 | 7 | 81 | |||||||||
Amortization of debt fair value adjustment | 0 | 0 | 0 | |||||||||
Merger-related commitments | 0 | [9] | 0 | [10] | 0 | [11],[12] | ||||||
Severance costs | 0 | 0 | 0 | |||||||||
Amortization of debt costs | 1 | 2 | 1 | |||||||||
Vacation accrual adjustment | [16] | 0 | ||||||||||
Change in environmental liabilities | 0 | |||||||||||
Lower of cost or market inventory adjustment | 0 | |||||||||||
Baltimore City conduit lease settlement | (28) | |||||||||||
Cash Working Capital order | (13) | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | 0 | ||||||||||
Other | (12) | (14) | (21) | |||||||||
Total other non-cash operating activities | 58 | 65 | 88 | |||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | 50 | 23 | (86) | |||||||||
Change in PPE related to ARO update | 1 | 0 | 1 | 0 | 0 | |||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 0 | 0 | ||||||||||
Acquisition of land | 0 | |||||||||||
Dissolution of financing trust due to long-term debt retirement | 8 | |||||||||||
Pepco Holdings LLC [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | 480 | 457 | ||||||||||
Amortization of Regulatory Asset | 260 | 218 | ||||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 0 | 0 | |||||||||
Total depreciation, amortization and accretion | 740 | 675 | ||||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 250 | 236 | ||||||||||
Income taxes (net of refunds) | (32) | (144) | ||||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 67 | 94 | ||||||||||
Gain (loss) on equity method investments | (1) | (1) | ||||||||||
Provision for uncollectible accounts | 28 | 19 | ||||||||||
Provision for excess and obsolete inventory | 0 | 2 | ||||||||||
Amortization of regulatory asset related to debt costs | 4 | 4 | ||||||||||
Amortization of rate stabilization deferral | 14 | (17) | ||||||||||
Amortization of debt fair value adjustment | (3) | (6) | ||||||||||
Merger-related commitments | 5 | [9] | (8) | [10] | ||||||||
Severance costs | 0 | 3 | ||||||||||
Amortization of debt costs | 3 | 4 | ||||||||||
Vacation accrual adjustment | [16] | 8 | ||||||||||
Change in environmental liabilities | 0 | |||||||||||
Other | 6 | (28) | ||||||||||
Total other non-cash operating activities | 143 | 58 | ||||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | 93 | (12) | ||||||||||
Change in PPE related to ARO update | 15 | 15 | 0 | |||||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 0 | |||||||||||
Acquisition of land | 3 | |||||||||||
Pepco Holdings LLC [Member] | Successor [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | 325 | |||||||||||
Amortization of Regulatory Asset | 190 | |||||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 0 | ||||||||||
Total depreciation, amortization and accretion | 515 | |||||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 209 | |||||||||||
Income taxes (net of refunds) | 258 | |||||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 86 | |||||||||||
Gain (loss) on equity method investments | 0 | |||||||||||
Provision for uncollectible accounts | 65 | |||||||||||
Provision for excess and obsolete inventory | 1 | |||||||||||
Amortization of regulatory asset related to debt costs | 3 | |||||||||||
Amortization of rate stabilization deferral | (5) | |||||||||||
Amortization of debt fair value adjustment | 0 | |||||||||||
Merger-related commitments | [11],[12] | 317 | ||||||||||
Severance costs | 56 | |||||||||||
Amortization of debt costs | 1 | |||||||||||
Lower of cost or market inventory adjustment | 0 | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 2 | 20 | ||||||||||
Other | (11) | |||||||||||
Total other non-cash operating activities | 515 | |||||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | 21 | |||||||||||
Change in PPE related to ARO update | 0 | 0 | ||||||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 0 | |||||||||||
Fair value of net assets contributed (distributed) in connection with the PHI merger, net of cash | [12],[20] | 127 | ||||||||||
Fair value of pension obligation transferred in connection with the PHI Merger, net of cash | [12],[20] | 53 | ||||||||||
Pepco Holdings LLC [Member] | Successor [Member] | noncash member [Member] | ||||||||||||
Other non-cash operating activities: | ||||||||||||
Merger-related commitments | 33 | |||||||||||
Non-cash investing and financing activities: | ||||||||||||
Assumption of member purchase liability | 29 | |||||||||||
Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | $ 94 | |||||||||||
Amortization of Regulatory Asset | 58 | |||||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 0 | ||||||||||
Total depreciation, amortization and accretion | 152 | |||||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 43 | |||||||||||
Income taxes (net of refunds) | 11 | |||||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 23 | |||||||||||
Gain (loss) on equity method investments | 0 | |||||||||||
Provision for uncollectible accounts | 16 | |||||||||||
Provision for excess and obsolete inventory | 1 | |||||||||||
Stock-based compensation costs | 3 | |||||||||||
Amortization of regulatory asset related to debt costs | 1 | |||||||||||
Amortization of rate stabilization deferral | 5 | |||||||||||
Amortization of debt fair value adjustment | 0 | |||||||||||
Merger-related commitments | [11],[12] | 0 | ||||||||||
Severance costs | 0 | |||||||||||
Amortization of debt costs | 0 | |||||||||||
Lower of cost or market inventory adjustment | 0 | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 0 | |||||||||||
Other | (3) | |||||||||||
Total other non-cash operating activities | 46 | |||||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | 11 | |||||||||||
Change in PPE related to ARO update | 0 | |||||||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 0 | |||||||||||
Potomac Electric Power Company [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | 218 | 203 | 175 | |||||||||
Amortization of Regulatory Asset | 167 | 118 | 120 | |||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 0 | 0 | 0 | ||||||||
Total depreciation, amortization and accretion | 385 | 321 | 295 | |||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 123 | 114 | 118 | |||||||||
Income taxes (net of refunds) | 41 | (104) | 216 | |||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 15 | 25 | 31 | |||||||||
Gain (loss) on equity method investments | 0 | 0 | 0 | |||||||||
Provision for uncollectible accounts | 11 | 8 | 29 | |||||||||
Provision for excess and obsolete inventory | 0 | 1 | 3 | |||||||||
Amortization of regulatory asset related to debt costs | 2 | 2 | 2 | |||||||||
Amortization of rate stabilization deferral | 14 | (17) | (12) | |||||||||
Amortization of debt fair value adjustment | 0 | 0 | 0 | |||||||||
Merger-related commitments | 0 | [9] | (6) | [10] | 125 | [11],[12] | ||||||
Severance costs | 0 | 0 | 0 | |||||||||
Amortization of debt costs | 2 | 2 | 0 | |||||||||
Vacation accrual adjustment | [16] | 8 | ||||||||||
Change in environmental liabilities | 0 | |||||||||||
Lower of cost or market inventory adjustment | 0 | |||||||||||
Asset Retirement Obligation, Revision of Estimate | 22 | 0 | ||||||||||
Other | (6) | (13) | (3) | |||||||||
Total other non-cash operating activities | 60 | (6) | 175 | |||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | 20 | 5 | 27 | |||||||||
Change in PPE related to ARO update | 12 | 0 | 12 | 0 | 0 | |||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 0 | 0 | ||||||||||
Acquisition of land | 0 | |||||||||||
Potomac Electric Power Company [Member] | noncash member [Member] | ||||||||||||
Other non-cash operating activities: | ||||||||||||
Merger-related commitments | 33 | |||||||||||
Delmarva Power & Light Company [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | 131 | 124 | 110 | |||||||||
Amortization of Regulatory Asset | 51 | 43 | 47 | |||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 0 | 0 | 0 | ||||||||
Total depreciation, amortization and accretion | 182 | 167 | 157 | |||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 56 | 49 | 47 | |||||||||
Income taxes (net of refunds) | (6) | (49) | 115 | |||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 6 | 13 | 18 | |||||||||
Gain (loss) on equity method investments | 0 | 0 | 0 | |||||||||
Provision for uncollectible accounts | 6 | 3 | 23 | |||||||||
Provision for excess and obsolete inventory | 0 | 1 | 1 | |||||||||
Amortization of regulatory asset related to debt costs | 1 | 1 | 1 | |||||||||
Amortization of rate stabilization deferral | 0 | 0 | 2 | |||||||||
Amortization of debt fair value adjustment | 0 | 0 | 0 | |||||||||
Merger-related commitments | 5 | [9] | (2) | [10] | 82 | [11],[12] | ||||||
Severance costs | 0 | 0 | 0 | |||||||||
Amortization of debt costs | 0 | 0 | 0 | |||||||||
Vacation accrual adjustment | [16] | 0 | ||||||||||
Change in environmental liabilities | 0 | |||||||||||
Lower of cost or market inventory adjustment | 0 | |||||||||||
Asset Retirement Obligation, Revision of Estimate | (1) | 1 | ||||||||||
Other | 7 | (7) | (14) | |||||||||
Total other non-cash operating activities | 24 | 9 | 114 | |||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | 22 | 4 | (12) | |||||||||
Change in PPE related to ARO update | 2 | 0 | 2 | 0 | 0 | |||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 0 | 0 | ||||||||||
Acquisition of land | 0 | |||||||||||
Atlantic City Electric Company [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Depreciation | 94 | 89 | 82 | |||||||||
Amortization of Regulatory Asset | 42 | 57 | 83 | |||||||||
Asset Retirement Obligation, Accretion Expense | [2] | 0 | 0 | 0 | ||||||||
Total depreciation, amortization and accretion | 136 | 146 | 165 | |||||||||
Cash paid (refunded) during the year: | ||||||||||||
Interest (net of amount capitalized) | 61 | 59 | 62 | |||||||||
Income taxes (net of refunds) | (12) | (2) | 200 | |||||||||
Other non-cash operating activities: | ||||||||||||
Pension and non-pension postretirement benefit costs | 12 | 13 | 15 | |||||||||
Gain (loss) on equity method investments | 0 | 0 | 0 | |||||||||
Provision for uncollectible accounts | 11 | 8 | 32 | |||||||||
Provision for excess and obsolete inventory | 0 | 0 | 1 | |||||||||
Amortization of regulatory asset related to debt costs | 1 | 1 | 1 | |||||||||
Amortization of rate stabilization deferral | 0 | 0 | 0 | |||||||||
Amortization of debt fair value adjustment | 0 | 0 | 0 | |||||||||
Merger-related commitments | 0 | [9] | 0 | [10] | 110 | [11],[12] | ||||||
Severance costs | 0 | 0 | 0 | |||||||||
Amortization of debt costs | 1 | 1 | 0 | |||||||||
Vacation accrual adjustment | [16] | 0 | ||||||||||
Change in environmental liabilities | 0 | |||||||||||
Lower of cost or market inventory adjustment | 0 | |||||||||||
Asset Retirement Obligation, Revision of Estimate | (1) | 2 | ||||||||||
Other | 0 | (6) | (6) | |||||||||
Total other non-cash operating activities | 24 | 17 | 155 | |||||||||
Non-cash investing and financing activities: | ||||||||||||
Increase (decrease) in capital expenditures not paid | 46 | (13) | 11 | |||||||||
Change in PPE related to ARO update | $ 1 | 0 | 1 | 0 | 0 | |||||||
Noncash or Part Noncash Acquisition, Fixed Assets Acquired | 0 | 0 | ||||||||||
Acquisition of land | 3 | |||||||||||
Other Intangible Assets [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | 58 | 57 | 52 | |||||||||
Other Intangible Assets [Member] | Exelon Generation Co L L C [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | 49 | 48 | 44 | |||||||||
Other Intangible Assets [Member] | Commonwealth Edison Co [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | 0 | 0 | 0 | |||||||||
Other Intangible Assets [Member] | PECO Energy Co [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | 0 | 0 | 0 | |||||||||
Other Intangible Assets [Member] | Baltimore Gas and Electric Company [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | 0 | 0 | 0 | |||||||||
Other Intangible Assets [Member] | Pepco Holdings LLC [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | 0 | 0 | ||||||||||
Other Intangible Assets [Member] | Pepco Holdings LLC [Member] | Successor [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | $ 0 | |||||||||||
Other Intangible Assets [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | $ 0 | |||||||||||
Other Intangible Assets [Member] | Potomac Electric Power Company [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | 0 | 0 | 0 | |||||||||
Other Intangible Assets [Member] | Delmarva Power & Light Company [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | 0 | 0 | 0 | |||||||||
Other Intangible Assets [Member] | Atlantic City Electric Company [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Intangible Assets | 0 | 0 | 0 | |||||||||
Unamortized Energy Contracts [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Power Contracts Emission Credits | [21] | 14 | 35 | 35 | ||||||||
Unamortized Energy Contracts [Member] | Exelon Generation Co L L C [Member] | ||||||||||||
Depreciation, amortization and accretion | ||||||||||||
Amortization of Power Contracts Emission Credits | [21] | $ 14 | $ 35 | $ 35 | ||||||||
[1] | Included in Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. | |||||||||||
[2] | Included in Operating and maintenance expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. | |||||||||||
[3] | Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning. | |||||||||||
[4] | {F|ahBzfndlYmZpbGluZ3MtaHJkcmoLEgZYTUxEb2MiXlhCUkxEb2NHZW5JbmZvOmVlYzRiNDIxOTkxNDRkN2ViNWYzYTRhOTVmMjFkNDYzfFRleHRTZWxlY3Rpb246ODE3Q0FGRTQ3ODgzNTMyQkFDNzc4ODYwRDFBNDI1OTMM} | |||||||||||
[5] | Includes the elimination of NDT fund activity for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning. | |||||||||||
[6] | Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations. | |||||||||||
[7] | Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations. | |||||||||||
[8] | Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations. | |||||||||||
[9] | See Note 5 - Mergers, Acquisitions and Dispositions for additional information. | |||||||||||
[10] | See Note 5 - Mergers, Acquisitions and Dispositions for additional information. | |||||||||||
[11] | Excludes $5 million of forgiveness of Accounts receivable related to merger commitments recorded in connection with the PHI Merger, the balance is included within Provision for uncollectible accounts. | |||||||||||
[12] | See Note 5 - Mergers, Acquisitions and Dispositions for additional information. | |||||||||||
[13] | Reflects the change in ComEd's distribution and energy efficiency formula rates. See Note 4 — Regulatory Matters for additional information. | |||||||||||
[14] | Reflects the change in ComEd's distribution and energy efficiency formula rates . See Note 4 — Regulatory Matters for additional information. | |||||||||||
[15] | Reflects the change in distribution rates pursuant to EIMA, which allows for the recovery of costs by a utility through a pre-established performance-based formula rate. See Note 4 — Regulatory Matters for additional information. | |||||||||||
[16] | On December 1, 2017, Exelon adopted a single, standard vacation accrual policy for all non-represented, non-craft (represented and craft policies remained unchanged) employees effective January 1, 2018. To reflect the new policy, Exelon recorded a one-time, $68 million pre-tax credit to expense to reverse 2018 vacation cost originally accrued throughout 2017 that will now be accrued ratably over the year in 2018. | |||||||||||
[17] | Reflects the transfer of nuclear fuel to Entergy under the cost reimbursement provisions of the FitzPatrick acquisition agreements. See Note 5 - Mergers, Acquisitions and Dispositions for additional information. | |||||||||||
[18] | See Note 14 — Income Taxes for additional information on the like-kind exchange tax position | |||||||||||
[19] | See Note 14 — Income Taxes for additional information on the like-kind exchange tax position. | |||||||||||
[20] | Immediately following closing of the PHI Merger, the net assets associated with PHI’s unregulated business interests were distributed by PHI to Exelon. Exelon contributed a portion of such net assets to Generation. | |||||||||||
[21] | Included in Operating revenues or Purchased power and fuel in the Registrants’ Consolidated Statements of Operations and Comprehensive Income |
Supplemental Financial Inform_6
Supplemental Financial Information Supplemental Financial Information - Supplemental Balance Sheet Information (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Mar. 24, 2016 | Mar. 23, 2016 | Dec. 31, 2015 | |
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | $ 1,349 | $ 898 | $ 635 | $ 6,502 | |||
Restricted cash | 247 | 207 | 253 | 205 | |||
Restricted cash included in other long-term assets | 185 | 85 | 26 | 5 | |||
Total cash, cash equivalents and restricted cash | 1,781 | 1,190 | 914 | 6,712 | |||
Contracts Receivable [Abstract] | |||||||
Unbilled customer revenues | [1] | 1,656 | 1,858 | ||||
Allowance for uncollectible accounts | [2] | (319) | (322) | ||||
Purchased Receivables [Abstract] | |||||||
Purchased receivables | 313 | 298 | |||||
Allowance for uncollectible accounts | [3] | (34) | (31) | ||||
Purchased receivables, net | 279 | 267 | |||||
Investments [Abstract] | |||||||
Total equity method investments | 267 | 297 | |||||
Equity investments without readily determinable fair values | 72 | 62 | |||||
Other Investments | 2 | ||||||
Total Investments | 625 | 640 | |||||
Accrued Expenses [Abstract] | |||||||
Compensation-related accruals | [4] | 1,191 | 978 | ||||
Taxes accrued | 412 | 373 | |||||
Interest accrued | 334 | 328 | |||||
Severance accrued | 44 | 58 | |||||
Other accrued expenses | 131 | 100 | |||||
Total accrued expenses | 2,112 | 1,837 | |||||
Financing Trusts | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | [5] | 14 | 14 | ||||
Bloom Energy | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 180 | 206 | |||||
NET Power | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 70 | 76 | |||||
Other Equity Method Investments | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 3 | 1 | |||||
Employee benefit trusts and investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | [6] | 244 | 244 | ||||
Other available for sale investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | 40 | 37 | |||||
Exelon Generation Co L L C [Member] | |||||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | 750 | 416 | 290 | 431 | |||
Restricted cash | 153 | 138 | 158 | 123 | |||
Restricted cash included in other long-term assets | 0 | 0 | 0 | 2 | |||
Total cash, cash equivalents and restricted cash | 903 | 554 | 448 | 556 | |||
Contracts Receivable [Abstract] | |||||||
Unbilled customer revenues | [1] | 965 | 1,017 | ||||
Allowance for uncollectible accounts | [2] | (104) | (114) | ||||
Investments [Abstract] | |||||||
Total equity method investments | 251 | 283 | |||||
Equity investments without readily determinable fair values | 72 | 62 | |||||
Other Investments | 2 | ||||||
Total Investments | 414 | 433 | |||||
Accrued Expenses [Abstract] | |||||||
Compensation-related accruals | [4] | 479 | 407 | ||||
Taxes accrued | 226 | 444 | |||||
Interest accrued | 77 | 78 | |||||
Severance accrued | 26 | 30 | |||||
Other accrued expenses | 90 | 63 | |||||
Total accrued expenses | 898 | 1,022 | |||||
Exelon Generation Co L L C [Member] | Financing Trusts | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | [5] | 0 | 0 | ||||
Exelon Generation Co L L C [Member] | Bloom Energy | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 180 | 206 | |||||
Exelon Generation Co L L C [Member] | NET Power | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 70 | 76 | |||||
Exelon Generation Co L L C [Member] | Other Equity Method Investments | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 1 | 1 | |||||
Exelon Generation Co L L C [Member] | Employee benefit trusts and investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | [6] | 49 | 51 | ||||
Exelon Generation Co L L C [Member] | Other available for sale investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | 40 | 37 | |||||
Commonwealth Edison Co [Member] | |||||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | 135 | 76 | 56 | 67 | |||
Restricted cash | 29 | 5 | 2 | 2 | |||
Restricted cash included in other long-term assets | 166 | 63 | 0 | 0 | |||
Total cash, cash equivalents and restricted cash | 330 | 144 | 58 | 69 | |||
Contracts Receivable [Abstract] | |||||||
Unbilled customer revenues | [1] | 223 | 242 | ||||
Allowance for uncollectible accounts | [2] | (81) | (73) | ||||
Purchased Receivables [Abstract] | |||||||
Purchased receivables | 94 | 87 | |||||
Allowance for uncollectible accounts | [3] | (17) | (14) | ||||
Purchased receivables, net | 77 | 73 | |||||
Investments [Abstract] | |||||||
Total equity method investments | 6 | 6 | |||||
Equity investments without readily determinable fair values | 0 | 0 | |||||
Other Investments | 0 | ||||||
Total Investments | 6 | 6 | |||||
Accrued Expenses [Abstract] | |||||||
Compensation-related accruals | [4] | 187 | 158 | ||||
Taxes accrued | 71 | 60 | |||||
Interest accrued | 105 | 102 | |||||
Severance accrued | 2 | 2 | |||||
Other accrued expenses | 8 | 5 | |||||
Total accrued expenses | 373 | 327 | |||||
Commonwealth Edison Co [Member] | Financing Trusts | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | [5] | 6 | 6 | ||||
Commonwealth Edison Co [Member] | Bloom Energy | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Commonwealth Edison Co [Member] | NET Power | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Commonwealth Edison Co [Member] | Other Equity Method Investments | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Commonwealth Edison Co [Member] | Employee benefit trusts and investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | [6] | 0 | 0 | ||||
Commonwealth Edison Co [Member] | Other available for sale investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | 0 | 0 | |||||
PECO Energy Co [Member] | |||||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | 130 | 271 | 63 | 295 | |||
Restricted cash | 5 | 4 | 4 | 3 | |||
Restricted cash included in other long-term assets | 0 | 0 | 0 | 0 | |||
Total cash, cash equivalents and restricted cash | 135 | 275 | 67 | 298 | |||
Contracts Receivable [Abstract] | |||||||
Unbilled customer revenues | [1] | 114 | 162 | ||||
Allowance for uncollectible accounts | [2] | (61) | (56) | ||||
Purchased Receivables [Abstract] | |||||||
Purchased receivables | 74 | 70 | |||||
Allowance for uncollectible accounts | [3] | (5) | (5) | ||||
Purchased receivables, net | 69 | 65 | |||||
Investments [Abstract] | |||||||
Total equity method investments | 8 | 8 | |||||
Equity investments without readily determinable fair values | 0 | 0 | |||||
Other Investments | 0 | ||||||
Total Investments | 25 | 25 | |||||
Accrued Expenses [Abstract] | |||||||
Compensation-related accruals | [4] | 49 | 64 | ||||
Taxes accrued | 28 | 15 | |||||
Interest accrued | 33 | 33 | |||||
Severance accrued | 0 | 0 | |||||
Other accrued expenses | 3 | 2 | |||||
Total accrued expenses | 113 | 114 | |||||
PECO Energy Co [Member] | Financing Trusts | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | [5] | 8 | 8 | ||||
PECO Energy Co [Member] | Bloom Energy | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
PECO Energy Co [Member] | NET Power | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
PECO Energy Co [Member] | Other Equity Method Investments | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
PECO Energy Co [Member] | Employee benefit trusts and investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | [6] | 17 | 17 | ||||
PECO Energy Co [Member] | Other available for sale investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | 0 | 0 | |||||
Baltimore Gas and Electric Company [Member] | |||||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | 7 | 17 | 23 | 9 | |||
Restricted cash | 6 | 1 | 24 | 24 | |||
Restricted cash included in other long-term assets | 0 | 0 | 3 | 3 | |||
Total cash, cash equivalents and restricted cash | 13 | 18 | 50 | 36 | |||
Contracts Receivable [Abstract] | |||||||
Unbilled customer revenues | [1] | 168 | 205 | ||||
Allowance for uncollectible accounts | [2] | (20) | (24) | ||||
Purchased Receivables [Abstract] | |||||||
Purchased receivables | 61 | 58 | |||||
Allowance for uncollectible accounts | [3] | (3) | (3) | ||||
Purchased receivables, net | 58 | 55 | |||||
Investments [Abstract] | |||||||
Total equity method investments | 0 | 0 | |||||
Equity investments without readily determinable fair values | 0 | 0 | |||||
Other Investments | 0 | ||||||
Total Investments | 5 | 5 | |||||
Accrued Expenses [Abstract] | |||||||
Compensation-related accruals | [4] | 68 | 58 | ||||
Taxes accrued | 46 | 71 | |||||
Interest accrued | 39 | 34 | |||||
Severance accrued | 0 | 0 | |||||
Other accrued expenses | 2 | 1 | |||||
Total accrued expenses | 155 | 164 | |||||
Baltimore Gas and Electric Company [Member] | Financing Trusts | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | [5] | 0 | 0 | ||||
Baltimore Gas and Electric Company [Member] | Bloom Energy | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Baltimore Gas and Electric Company [Member] | NET Power | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Baltimore Gas and Electric Company [Member] | Other Equity Method Investments | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Baltimore Gas and Electric Company [Member] | Employee benefit trusts and investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | [6] | 5 | 5 | ||||
Baltimore Gas and Electric Company [Member] | Other available for sale investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | 0 | 0 | |||||
Pepco Holdings LLC [Member] | |||||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | 124 | 30 | |||||
Restricted cash | 43 | 42 | |||||
Restricted cash included in other long-term assets | 19 | 23 | |||||
Total cash, cash equivalents and restricted cash | 186 | 95 | 236 | ||||
Contracts Receivable [Abstract] | |||||||
Unbilled customer revenues | [1] | 186 | 232 | ||||
Allowance for uncollectible accounts | [2] | (53) | (55) | ||||
Purchased Receivables [Abstract] | |||||||
Purchased receivables | 84 | 83 | |||||
Allowance for uncollectible accounts | [3] | (9) | (9) | ||||
Purchased receivables, net | 75 | 74 | |||||
Investments [Abstract] | |||||||
Total equity method investments | 0 | 0 | |||||
Equity investments without readily determinable fair values | 0 | 0 | |||||
Other Investments | 0 | ||||||
Total Investments | 130 | 132 | |||||
Accrued Expenses [Abstract] | |||||||
Compensation-related accruals | [4] | 99 | 106 | ||||
Taxes accrued | 74 | 61 | |||||
Interest accrued | 50 | 48 | |||||
Severance accrued | 5 | 17 | |||||
Other accrued expenses | 28 | 29 | |||||
Total accrued expenses | 256 | 261 | |||||
Pepco Holdings LLC [Member] | Successor [Member] | |||||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | 170 | ||||||
Restricted cash | 43 | ||||||
Restricted cash included in other long-term assets | 23 | ||||||
Total cash, cash equivalents and restricted cash | 236 | $ 348 | |||||
Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | $ 319 | 26 | |||||
Restricted cash | 11 | 14 | |||||
Restricted cash included in other long-term assets | 18 | 18 | |||||
Total cash, cash equivalents and restricted cash | $ 348 | 58 | |||||
Pepco Holdings LLC [Member] | Financing Trusts | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | [5] | 0 | 0 | ||||
Pepco Holdings LLC [Member] | Bloom Energy | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Pepco Holdings LLC [Member] | NET Power | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Pepco Holdings LLC [Member] | Other Equity Method Investments | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Pepco Holdings LLC [Member] | Employee benefit trusts and investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | [6] | 130 | 132 | ||||
Pepco Holdings LLC [Member] | Other available for sale investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | 0 | 0 | |||||
Potomac Electric Power Company [Member] | |||||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | 16 | 5 | 9 | 5 | |||
Restricted cash | 37 | 35 | 33 | 2 | |||
Restricted cash included in other long-term assets | 0 | 0 | 0 | 0 | |||
Total cash, cash equivalents and restricted cash | 53 | 40 | 42 | 7 | |||
Contracts Receivable [Abstract] | |||||||
Unbilled customer revenues | [1] | 97 | 133 | ||||
Allowance for uncollectible accounts | [2] | (21) | (21) | ||||
Purchased Receivables [Abstract] | |||||||
Purchased receivables | 57 | 56 | |||||
Allowance for uncollectible accounts | [3] | (5) | (5) | ||||
Purchased receivables, net | 52 | 51 | |||||
Investments [Abstract] | |||||||
Total equity method investments | 0 | 0 | |||||
Equity investments without readily determinable fair values | 0 | 0 | |||||
Other Investments | 0 | ||||||
Total Investments | 105 | 102 | |||||
Accrued Expenses [Abstract] | |||||||
Compensation-related accruals | [4] | 29 | 29 | ||||
Taxes accrued | 58 | 68 | |||||
Interest accrued | 25 | 23 | |||||
Severance accrued | 0 | 0 | |||||
Other accrued expenses | 14 | 17 | |||||
Total accrued expenses | 126 | 137 | |||||
Potomac Electric Power Company [Member] | Financing Trusts | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | [5] | 0 | 0 | ||||
Potomac Electric Power Company [Member] | Bloom Energy | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Potomac Electric Power Company [Member] | NET Power | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Potomac Electric Power Company [Member] | Other Equity Method Investments | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Potomac Electric Power Company [Member] | Employee benefit trusts and investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | [6] | 105 | 102 | ||||
Potomac Electric Power Company [Member] | Other available for sale investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | 0 | 0 | |||||
Delmarva Power & Light Company [Member] | |||||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | 23 | 2 | 46 | 5 | |||
Restricted cash | 1 | 0 | 0 | 0 | |||
Restricted cash included in other long-term assets | 0 | 0 | 0 | 0 | |||
Total cash, cash equivalents and restricted cash | 24 | 2 | 46 | 5 | |||
Contracts Receivable [Abstract] | |||||||
Unbilled customer revenues | [1] | 59 | 68 | ||||
Allowance for uncollectible accounts | [2] | (13) | (16) | ||||
Purchased Receivables [Abstract] | |||||||
Purchased receivables | 8 | 9 | |||||
Allowance for uncollectible accounts | [3] | (1) | (1) | ||||
Purchased receivables, net | 7 | 8 | |||||
Investments [Abstract] | |||||||
Total equity method investments | 0 | 0 | |||||
Equity investments without readily determinable fair values | 0 | 0 | |||||
Other Investments | 0 | ||||||
Total Investments | 0 | 0 | |||||
Accrued Expenses [Abstract] | |||||||
Compensation-related accruals | [4] | 19 | 17 | ||||
Taxes accrued | 4 | 4 | |||||
Interest accrued | 8 | 8 | |||||
Severance accrued | 0 | 0 | |||||
Other accrued expenses | 8 | 6 | |||||
Total accrued expenses | 39 | 35 | |||||
Delmarva Power & Light Company [Member] | Financing Trusts | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | [5] | 0 | 0 | ||||
Delmarva Power & Light Company [Member] | Bloom Energy | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Delmarva Power & Light Company [Member] | NET Power | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Delmarva Power & Light Company [Member] | Other Equity Method Investments | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Delmarva Power & Light Company [Member] | Employee benefit trusts and investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | [6] | 0 | 0 | ||||
Delmarva Power & Light Company [Member] | Other available for sale investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | 0 | 0 | |||||
Atlantic City Electric Company [Member] | |||||||
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract] | |||||||
Cash and cash equivalents | 7 | 2 | 101 | 3 | |||
Restricted cash | 4 | 6 | 9 | 12 | |||
Restricted cash included in other long-term assets | 19 | 23 | 23 | 18 | |||
Total cash, cash equivalents and restricted cash | 30 | 31 | $ 133 | $ 33 | |||
Contracts Receivable [Abstract] | |||||||
Unbilled customer revenues | [1] | 30 | 31 | ||||
Allowance for uncollectible accounts | [2] | (19) | (18) | ||||
Purchased Receivables [Abstract] | |||||||
Purchased receivables | 19 | 18 | |||||
Allowance for uncollectible accounts | [3] | (3) | (3) | ||||
Purchased receivables, net | 16 | 15 | |||||
Investments [Abstract] | |||||||
Total equity method investments | 0 | 0 | |||||
Equity investments without readily determinable fair values | 0 | 0 | |||||
Other Investments | 0 | ||||||
Total Investments | 0 | 0 | |||||
Accrued Expenses [Abstract] | |||||||
Compensation-related accruals | [4] | 12 | 11 | ||||
Taxes accrued | 5 | 5 | |||||
Interest accrued | 12 | 12 | |||||
Severance accrued | 0 | 0 | |||||
Other accrued expenses | 6 | 5 | |||||
Total accrued expenses | 35 | 33 | |||||
Atlantic City Electric Company [Member] | Financing Trusts | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | [5] | 0 | 0 | ||||
Atlantic City Electric Company [Member] | Bloom Energy | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Atlantic City Electric Company [Member] | NET Power | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Atlantic City Electric Company [Member] | Other Equity Method Investments | |||||||
Investments [Abstract] | |||||||
Equity Method Investments | 0 | 0 | |||||
Atlantic City Electric Company [Member] | Employee benefit trusts and investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | [6] | 0 | 0 | ||||
Atlantic City Electric Company [Member] | Other available for sale investments | |||||||
Investments [Abstract] | |||||||
Available for sale investments | $ 0 | $ 0 | |||||
[1] | Represents unbilled portion of receivables estimated under Exelon’s unbilled critical accounting policy. | ||||||
[2] | Includes the estimated allowance for uncollectible accounts on billed customer and other accounts receivable. | ||||||
[3] | For ComEd, BGE, Pepco and DPL, reflects the incremental allowance for uncollectible accounts recorded, which is in addition to the purchase discount. For ComEd, the incremental uncollectible accounts expense is recovered through a rate rider. BGE, Pepco and DPL recover actual write-offs which are reflected in the POR discount rate. | ||||||
[4] | Primarily includes accrued payroll, bonuses and other incentives, vacation and benefits. | ||||||
[5] | Includes investments in affiliated financing trusts, which were not consolidated within the financial statements of Exelon and are shown as investments in the Consolidated Balance Sheets. See Note 1 — Significant Accounting Policies for additional information. | ||||||
[6] | The Registrants’ debt and equity security investments are recorded at fair market value. |
Segment Information Segment Inf
Segment Information Segment Information - Narrative (Details) | 12 Months Ended |
Dec. 31, 2018Reportable_segment | |
Segment Reporting Information [Line Items] | |
Number of reportable segments | 12 |
Exelon Generation Co L L C [Member] | |
Segment Reporting Information [Line Items] | |
Number of reportable segments | 6 |
Pepco Holdings LLC [Member] | |
Segment Reporting Information [Line Items] | |
Number of reportable segments | 3 |
Segment Information Segment I_2
Segment Information Segment Information - Reconciliation to Consolidated Financial Statements (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||||||||||||
Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2017 | Jun. 30, 2017 | Mar. 31, 2017 | Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | $ 0 | $ 0 | |||||||||||||
Rate-regulated natural gas revenues | 0 | 0 | |||||||||||||
Revenues | $ 8,814 | $ 9,403 | $ 8,076 | $ 9,693 | $ 8,384 | $ 8,768 | $ 7,665 | $ 8,747 | $ 35,985 | 33,565 | 31,366 | ||||
Operating revenues from affiliates | 0 | 0 | |||||||||||||
Depreciation and amortization | 4,353 | 3,828 | 3,936 | ||||||||||||
Operating Expenses | [1] | 32,143 | 29,619 | 28,106 | |||||||||||
Interest expense, net | 1,554 | 1,560 | 1,536 | ||||||||||||
Income (loss) before income taxes | 2,232 | 3,782 | 1,973 | ||||||||||||
Income taxes | 26 | 120 | (126) | 753 | |||||||||||
Net income (loss) | 2,084 | 3,876 | 1,196 | ||||||||||||
Capital expenditures | 7,594 | 7,584 | 8,553 | ||||||||||||
Assets | [2] | 119,666 | 116,770 | 119,666 | 116,770 | ||||||||||
Pepco Holdings LLC [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | 4,609 | 4,428 | |||||||||||||
Rate-regulated natural gas revenues | 181 | 161 | |||||||||||||
Revenues | 1,117 | 1,361 | 1,076 | 1,251 | 1,121 | 1,310 | 1,074 | 1,175 | 4,805 | 4,679 | |||||
Operating revenues from affiliates | 15 | 50 | |||||||||||||
Income (loss) before income taxes | 432 | 578 | |||||||||||||
Income taxes | 35 | 217 | |||||||||||||
Net income (loss) | 398 | 362 | |||||||||||||
Capital expenditures | 1,375 | 1,396 | |||||||||||||
Assets | [3] | 21,984 | 21,247 | 21,984 | 21,247 | ||||||||||
Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | $ 3,463 | 4,428 | |||||||||||||
Rate-regulated natural gas revenues | 92 | 161 | |||||||||||||
Revenues | 3,643 | 4,679 | |||||||||||||
Operating revenues from affiliates | 45 | 15 | 50 | ||||||||||||
Income (loss) before income taxes | (58) | ||||||||||||||
Income taxes | 3 | ||||||||||||||
Net income (loss) | $ (61) | (61) | |||||||||||||
Capital expenditures | 1,008 | ||||||||||||||
Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | $ 1,122 | ||||||||||||||
Rate-regulated natural gas revenues | 57 | ||||||||||||||
Revenues | 1,153 | ||||||||||||||
Operating revenues from affiliates | 0 | ||||||||||||||
Income (loss) before income taxes | 36 | ||||||||||||||
Income taxes | 17 | ||||||||||||||
Net income (loss) | 19 | ||||||||||||||
Capital expenditures | 273 | ||||||||||||||
Exelon Generation Co L L C [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | 0 | 0 | |||||||||||||
Rate-regulated natural gas revenues | 0 | 0 | |||||||||||||
Revenues | 5,069 | $ 5,278 | $ 4,579 | $ 5,512 | 4,657 | $ 4,750 | $ 4,216 | $ 4,878 | 20,437 | 18,500 | 17,757 | ||||
Operating revenues from affiliates | 1,268 | 1,115 | 1,439 | ||||||||||||
Income (loss) before income taxes | 365 | 1,455 | 857 | ||||||||||||
Income taxes | (108) | (1,376) | 282 | ||||||||||||
Net income (loss) | 443 | 2,798 | 550 | ||||||||||||
Capital expenditures | 2,242 | 2,259 | 3,078 | ||||||||||||
Assets | [4] | 47,556 | 48,457 | 47,556 | 48,457 | ||||||||||
Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Competitive businesses electric revenues | [1] | 16,155 | 14,227 | 13,970 | |||||||||||
Competitive businesses natural gas revenues | [1] | 2,710 | 2,575 | 2,146 | |||||||||||
Competitive businesses other revenues | [1] | 303 | 592 | 207 | |||||||||||
Rate-regulated electric revenues | [1] | 15,344 | 14,840 | 13,869 | |||||||||||
Rate-regulated natural gas revenues | [1] | 1,470 | 1,333 | 1,166 | |||||||||||
Shared service and other revenues | [1] | 3 | 0 | 7 | |||||||||||
Revenues | [1] | 35,985 | 33,567 | 31,365 | |||||||||||
Operating Segments [Member] | Pepco Holdings LLC [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Revenues | [5] | 47 | |||||||||||||
Operating Segments [Member] | Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Revenues | [5] | 43 | |||||||||||||
Operating Segments [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Revenues | [5] | 0 | |||||||||||||
Corporate, Non-Segment [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | (1) | 7 | 10 | ||||||||||||
Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Competitive businesses electric revenues | [1] | (1,256) | (1,105) | (1,430) | |||||||||||
Competitive businesses natural gas revenues | [1] | (8) | 0 | 0 | |||||||||||
Competitive businesses other revenues | [1] | (5) | (1) | (4) | |||||||||||
Rate-regulated electric revenues | [1] | (45) | (29) | (31) | |||||||||||
Rate-regulated natural gas revenues | [1] | (20) | (10) | (13) | |||||||||||
Shared service and other revenues | [1] | (1,960) | (1,880) | (1,686) | |||||||||||
Revenues | [1] | (3,294) | (3,025) | (3,164) | |||||||||||
Operating revenues from affiliates | [6] | 1 | 2 | 5 | |||||||||||
Depreciation and amortization | 0 | 0 | 0 | ||||||||||||
Operating Expenses | [1] | (3,341) | (3,026) | (3,164) | |||||||||||
Interest expense, net | 0 | 0 | 0 | ||||||||||||
Income (loss) before income taxes | (1) | (2) | (5) | ||||||||||||
Income taxes | 0 | 0 | 0 | ||||||||||||
Net income (loss) | (1) | (2) | (5) | ||||||||||||
Capital expenditures | 0 | 0 | 0 | ||||||||||||
Assets | (9,800) | (10,552) | (9,800) | (10,552) | |||||||||||
Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | (17) | (14) | ||||||||||||
Rate-regulated natural gas revenues | [7] | 0 | 0 | ||||||||||||
Shared service and other revenues | [7] | (420) | (3) | ||||||||||||
Revenues | [7] | (437) | (17) | ||||||||||||
Operating revenues from affiliates | (437) | (19) | |||||||||||||
Depreciation and amortization | 0 | (1) | |||||||||||||
Operating Expenses | (435) | (17) | |||||||||||||
Interest expense, net | 0 | (1) | |||||||||||||
Income (loss) before income taxes | (408) | (404) | |||||||||||||
Income taxes | (2) | 0 | |||||||||||||
Net income (loss) | 15 | 50 | |||||||||||||
Capital expenditures | 0 | 0 | |||||||||||||
Assets | (5,421) | (4,987) | (5,421) | (4,987) | |||||||||||
Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | (13) | |||||||||||||
Rate-regulated natural gas revenues | [7] | 0 | |||||||||||||
Shared service and other revenues | [7] | 0 | |||||||||||||
Revenues | [7] | (13) | |||||||||||||
Operating revenues from affiliates | (13) | ||||||||||||||
Depreciation and amortization | 0 | ||||||||||||||
Operating Expenses | (13) | ||||||||||||||
Interest expense, net | 0 | ||||||||||||||
Income (loss) before income taxes | 71 | ||||||||||||||
Income taxes | 0 | ||||||||||||||
Net income (loss) | 45 | ||||||||||||||
Capital expenditures | 0 | ||||||||||||||
Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | (4) | |||||||||||||
Rate-regulated natural gas revenues | [7] | 0 | |||||||||||||
Shared service and other revenues | [7] | 0 | |||||||||||||
Revenues | [7] | (4) | |||||||||||||
Operating revenues from affiliates | (4) | ||||||||||||||
Depreciation and amortization | (4) | ||||||||||||||
Operating Expenses | (3) | ||||||||||||||
Interest expense, net | (2) | ||||||||||||||
Income (loss) before income taxes | (118) | ||||||||||||||
Income taxes | 0 | ||||||||||||||
Net income (loss) | 0 | ||||||||||||||
Capital expenditures | 0 | ||||||||||||||
Exelon Generation Co L L C [Member] | Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Competitive businesses electric revenues | [1],[8] | 17,411 | 15,332 | 15,400 | |||||||||||
Competitive businesses natural gas revenues | [1],[8] | 2,718 | 2,575 | 2,146 | |||||||||||
Competitive businesses other revenues | [1],[8] | 308 | 593 | 211 | |||||||||||
Rate-regulated electric revenues | [1],[8] | 0 | 0 | 0 | |||||||||||
Rate-regulated natural gas revenues | [1],[8] | 0 | 0 | 0 | |||||||||||
Shared service and other revenues | [1],[8] | 0 | 0 | 0 | |||||||||||
Revenues | [1],[8] | 20,437 | 18,500 | 17,757 | |||||||||||
Depreciation and amortization | [8] | 1,797 | 1,457 | 1,879 | |||||||||||
Operating Expenses | [1],[8] | 19,510 | 18,001 | 16,878 | |||||||||||
Interest expense, net | [8] | 432 | 440 | 364 | |||||||||||
Income (loss) before income taxes | [8] | 365 | 1,455 | 857 | |||||||||||
Income taxes | [8] | (108) | (1,376) | 282 | |||||||||||
Net income (loss) | [8] | 443 | 2,798 | 550 | |||||||||||
Capital expenditures | [8] | 2,242 | 2,259 | 3,078 | |||||||||||
Assets | [8] | 47,556 | 48,457 | 47,556 | 48,457 | ||||||||||
Exelon Generation Co L L C [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [6],[8] | 1,269 | 1,110 | 1,428 | |||||||||||
Commonwealth Edison Co [Member] | Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Competitive businesses electric revenues | [1] | 0 | 0 | 0 | |||||||||||
Competitive businesses natural gas revenues | [1] | 0 | 0 | 0 | |||||||||||
Competitive businesses other revenues | [1] | 0 | 0 | 0 | |||||||||||
Rate-regulated electric revenues | [1] | 5,882 | 5,536 | 5,254 | |||||||||||
Rate-regulated natural gas revenues | [1] | 0 | 0 | 0 | |||||||||||
Shared service and other revenues | [1] | 0 | 0 | 0 | |||||||||||
Revenues | [1] | 5,882 | 5,536 | 5,254 | |||||||||||
Depreciation and amortization | 940 | 850 | 775 | ||||||||||||
Operating Expenses | [1] | 4,741 | 4,214 | 4,056 | |||||||||||
Interest expense, net | 347 | 361 | 461 | ||||||||||||
Income (loss) before income taxes | 832 | 984 | 679 | ||||||||||||
Income taxes | 168 | 417 | 301 | ||||||||||||
Net income (loss) | 664 | 567 | 378 | ||||||||||||
Capital expenditures | 2,126 | 2,250 | 2,734 | ||||||||||||
Assets | 31,213 | 29,726 | 31,213 | 29,726 | |||||||||||
Commonwealth Edison Co [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [6] | 27 | 15 | 15 | |||||||||||
PECO Energy Co [Member] | Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Competitive businesses electric revenues | [1] | 0 | 0 | 0 | |||||||||||
Competitive businesses natural gas revenues | [1] | 0 | 0 | 0 | |||||||||||
Competitive businesses other revenues | [1] | 0 | 0 | 0 | |||||||||||
Rate-regulated electric revenues | [1] | 2,470 | 2,375 | 2,531 | |||||||||||
Rate-regulated natural gas revenues | [1] | 568 | 495 | 463 | |||||||||||
Shared service and other revenues | [1] | 0 | 0 | 0 | |||||||||||
Revenues | [1] | 3,038 | 2,870 | 2,994 | |||||||||||
Depreciation and amortization | 301 | 286 | 270 | ||||||||||||
Operating Expenses | [1] | 2,452 | 2,215 | 2,292 | |||||||||||
Interest expense, net | 129 | 126 | 123 | ||||||||||||
Income (loss) before income taxes | 466 | 538 | 587 | ||||||||||||
Income taxes | 6 | 104 | 149 | ||||||||||||
Net income (loss) | 460 | 434 | 438 | ||||||||||||
Capital expenditures | 849 | 732 | 686 | ||||||||||||
Assets | 10,642 | 10,170 | 10,642 | 10,170 | |||||||||||
PECO Energy Co [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [6] | 8 | 7 | 8 | |||||||||||
Baltimore Gas and Electric Company [Member] | Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Competitive businesses electric revenues | [1] | 0 | 0 | 0 | |||||||||||
Competitive businesses natural gas revenues | [1] | 0 | 0 | 0 | |||||||||||
Competitive businesses other revenues | [1] | 0 | 0 | 0 | |||||||||||
Rate-regulated electric revenues | [1] | 2,428 | 2,489 | 2,609 | |||||||||||
Rate-regulated natural gas revenues | [1] | 741 | 687 | 624 | |||||||||||
Shared service and other revenues | [1] | 0 | 0 | 0 | |||||||||||
Revenues | [1] | 3,169 | 3,176 | 3,233 | |||||||||||
Depreciation and amortization | 483 | 473 | 423 | ||||||||||||
Operating Expenses | [1] | 2,696 | 2,562 | 2,683 | |||||||||||
Interest expense, net | 106 | 105 | 103 | ||||||||||||
Income (loss) before income taxes | 387 | 525 | 468 | ||||||||||||
Income taxes | 74 | 218 | 174 | ||||||||||||
Net income (loss) | 313 | 307 | 294 | ||||||||||||
Capital expenditures | 959 | 882 | 934 | ||||||||||||
Assets | 9,716 | 9,104 | 9,716 | 9,104 | |||||||||||
Baltimore Gas and Electric Company [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [6] | 29 | 16 | 21 | |||||||||||
Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Revenues | 3,643 | ||||||||||||||
Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Revenues | 1,153 | ||||||||||||||
Pepco Holdings LLC [Member] | Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Competitive businesses electric revenues | [1],[9] | 0 | 0 | ||||||||||||
Competitive businesses natural gas revenues | [1],[9] | 0 | 0 | ||||||||||||
Competitive businesses other revenues | [1],[9] | 0 | 0 | ||||||||||||
Rate-regulated electric revenues | [1],[7],[9] | 4,609 | 4,469 | ||||||||||||
Rate-regulated natural gas revenues | [1],[7],[9] | 181 | 161 | ||||||||||||
Shared service and other revenues | [1],[7],[9] | 15 | 49 | ||||||||||||
Revenues | [1],[7],[9] | 4,805 | 4,679 | ||||||||||||
Depreciation and amortization | [9] | 740 | 675 | ||||||||||||
Operating Expenses | [1],[9] | 4,156 | 3,911 | ||||||||||||
Interest expense, net | [9] | 261 | 245 | ||||||||||||
Income (loss) before income taxes | [9] | 432 | 578 | ||||||||||||
Income taxes | [9] | 35 | 217 | ||||||||||||
Net income (loss) | [9] | 398 | 362 | ||||||||||||
Capital expenditures | [9] | 1,375 | 1,396 | ||||||||||||
Assets | 21,984 | 21,247 | 21,984 | 21,247 | |||||||||||
Pepco Holdings LLC [Member] | Operating Segments [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Competitive businesses electric revenues | [1],[9] | 0 | |||||||||||||
Competitive businesses natural gas revenues | [1],[9] | 0 | |||||||||||||
Competitive businesses other revenues | [1],[9] | 0 | |||||||||||||
Rate-regulated electric revenues | [1],[7],[9] | 3,506 | |||||||||||||
Rate-regulated natural gas revenues | [1],[7],[9] | 92 | |||||||||||||
Shared service and other revenues | [1],[7],[9] | 45 | |||||||||||||
Revenues | [1],[7],[9] | 3,643 | |||||||||||||
Depreciation and amortization | [9] | 515 | |||||||||||||
Operating Expenses | [1],[9] | 3,549 | |||||||||||||
Interest expense, net | [9] | 195 | |||||||||||||
Income (loss) before income taxes | [9] | (58) | |||||||||||||
Income taxes | [9] | 3 | |||||||||||||
Net income (loss) | [9] | (61) | |||||||||||||
Capital expenditures | [9] | 1,008 | |||||||||||||
Assets | [9] | 21,984 | 21,247 | 21,984 | 21,247 | ||||||||||
Pepco Holdings LLC [Member] | Operating Segments [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | 1,096 | |||||||||||||
Rate-regulated natural gas revenues | [7] | 57 | |||||||||||||
Shared service and other revenues | [7] | 0 | |||||||||||||
Revenues | [7] | 1,153 | |||||||||||||
Depreciation and amortization | 152 | ||||||||||||||
Operating Expenses | 1,048 | ||||||||||||||
Interest expense, net | 65 | ||||||||||||||
Income (loss) before income taxes | 36 | ||||||||||||||
Income taxes | 17 | ||||||||||||||
Net income (loss) | 19 | ||||||||||||||
Capital expenditures | 273 | ||||||||||||||
Pepco Holdings LLC [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [6],[9] | 15 | 50 | ||||||||||||
Pepco Holdings LLC [Member] | Intersegment Eliminations [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [6],[9] | 45 | |||||||||||||
Pepco Holdings LLC [Member] | Intersegment Eliminations [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 0 | ||||||||||||||
Potomac Electric Power Company [Member] | Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | 2,239 | 2,158 | ||||||||||||
Rate-regulated natural gas revenues | [7] | 0 | 0 | ||||||||||||
Shared service and other revenues | [7] | 0 | 0 | ||||||||||||
Revenues | [7] | 2,239 | 2,158 | ||||||||||||
Depreciation and amortization | 385 | 321 | |||||||||||||
Operating Expenses | 1,919 | 1,760 | |||||||||||||
Interest expense, net | 128 | 121 | |||||||||||||
Income (loss) before income taxes | 223 | 310 | |||||||||||||
Income taxes | 13 | 105 | |||||||||||||
Net income (loss) | 210 | 205 | |||||||||||||
Capital expenditures | 656 | 628 | |||||||||||||
Assets | 8,299 | 7,832 | 8,299 | 7,832 | |||||||||||
Potomac Electric Power Company [Member] | Operating Segments [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | 1,675 | |||||||||||||
Rate-regulated natural gas revenues | [7] | 0 | |||||||||||||
Shared service and other revenues | [7] | 0 | |||||||||||||
Revenues | [7] | 1,675 | |||||||||||||
Depreciation and amortization | 224 | ||||||||||||||
Operating Expenses | 1,577 | ||||||||||||||
Interest expense, net | 98 | ||||||||||||||
Income (loss) before income taxes | 36 | ||||||||||||||
Income taxes | 26 | ||||||||||||||
Net income (loss) | 10 | ||||||||||||||
Capital expenditures | 489 | ||||||||||||||
Potomac Electric Power Company [Member] | Operating Segments [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | 511 | |||||||||||||
Rate-regulated natural gas revenues | [7] | 0 | |||||||||||||
Shared service and other revenues | [7] | 0 | |||||||||||||
Revenues | [7] | 511 | |||||||||||||
Depreciation and amortization | 71 | ||||||||||||||
Operating Expenses | 443 | ||||||||||||||
Interest expense, net | 29 | ||||||||||||||
Income (loss) before income taxes | 47 | ||||||||||||||
Income taxes | 15 | ||||||||||||||
Net income (loss) | 32 | ||||||||||||||
Capital expenditures | 97 | ||||||||||||||
Potomac Electric Power Company [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 6 | 6 | |||||||||||||
Potomac Electric Power Company [Member] | Intersegment Eliminations [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 4 | ||||||||||||||
Potomac Electric Power Company [Member] | Intersegment Eliminations [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 1 | ||||||||||||||
Delmarva Power & Light Company [Member] | Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | 1,151 | 1,139 | ||||||||||||
Rate-regulated natural gas revenues | [7] | 181 | 161 | ||||||||||||
Shared service and other revenues | [7] | 0 | 0 | ||||||||||||
Revenues | [7] | 1,332 | 1,300 | ||||||||||||
Depreciation and amortization | 182 | 167 | |||||||||||||
Operating Expenses | 1,143 | 1,071 | |||||||||||||
Interest expense, net | 58 | 51 | |||||||||||||
Income (loss) before income taxes | 142 | 192 | |||||||||||||
Income taxes | 22 | 71 | |||||||||||||
Net income (loss) | 120 | 121 | |||||||||||||
Capital expenditures | 364 | 428 | |||||||||||||
Assets | 4,588 | 4,357 | 4,588 | 4,357 | |||||||||||
Delmarva Power & Light Company [Member] | Operating Segments [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | 850 | |||||||||||||
Rate-regulated natural gas revenues | [7] | 92 | |||||||||||||
Shared service and other revenues | [7] | 0 | |||||||||||||
Revenues | [7] | 942 | |||||||||||||
Depreciation and amortization | 120 | ||||||||||||||
Operating Expenses | 952 | ||||||||||||||
Interest expense, net | 38 | ||||||||||||||
Income (loss) before income taxes | (30) | ||||||||||||||
Income taxes | 5 | ||||||||||||||
Net income (loss) | (35) | ||||||||||||||
Capital expenditures | 277 | ||||||||||||||
Delmarva Power & Light Company [Member] | Operating Segments [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | 279 | |||||||||||||
Rate-regulated natural gas revenues | [7] | 56 | |||||||||||||
Shared service and other revenues | [7] | 0 | |||||||||||||
Revenues | [7] | 335 | |||||||||||||
Depreciation and amortization | 37 | ||||||||||||||
Operating Expenses | 284 | ||||||||||||||
Interest expense, net | 12 | ||||||||||||||
Income (loss) before income taxes | 43 | ||||||||||||||
Income taxes | 17 | ||||||||||||||
Net income (loss) | 26 | ||||||||||||||
Capital expenditures | 72 | ||||||||||||||
Delmarva Power & Light Company [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 8 | 8 | |||||||||||||
Delmarva Power & Light Company [Member] | Intersegment Eliminations [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 5 | ||||||||||||||
Delmarva Power & Light Company [Member] | Intersegment Eliminations [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 2 | ||||||||||||||
Atlantic City Electric Company [Member] | Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | 1,236 | 1,186 | ||||||||||||
Rate-regulated natural gas revenues | [7] | 0 | 0 | ||||||||||||
Shared service and other revenues | [7] | 0 | 0 | ||||||||||||
Revenues | [7] | 1,236 | 1,186 | ||||||||||||
Depreciation and amortization | 136 | 146 | |||||||||||||
Operating Expenses | 1,087 | 1,029 | |||||||||||||
Interest expense, net | 64 | 61 | |||||||||||||
Income (loss) before income taxes | 87 | 103 | |||||||||||||
Income taxes | 12 | 26 | |||||||||||||
Net income (loss) | 75 | 77 | |||||||||||||
Capital expenditures | 335 | 312 | |||||||||||||
Assets | 3,699 | 3,445 | 3,699 | 3,445 | |||||||||||
Atlantic City Electric Company [Member] | Operating Segments [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | 989 | |||||||||||||
Rate-regulated natural gas revenues | [7] | 0 | |||||||||||||
Shared service and other revenues | [7] | 0 | |||||||||||||
Revenues | [7] | 989 | |||||||||||||
Depreciation and amortization | 128 | ||||||||||||||
Operating Expenses | 1,000 | ||||||||||||||
Interest expense, net | 47 | ||||||||||||||
Income (loss) before income taxes | (51) | ||||||||||||||
Income taxes | (5) | ||||||||||||||
Net income (loss) | (47) | ||||||||||||||
Capital expenditures | 218 | ||||||||||||||
Atlantic City Electric Company [Member] | Operating Segments [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7] | 268 | |||||||||||||
Rate-regulated natural gas revenues | [7] | 0 | |||||||||||||
Shared service and other revenues | [7] | 0 | |||||||||||||
Revenues | [7] | 268 | |||||||||||||
Depreciation and amortization | 37 | ||||||||||||||
Operating Expenses | 251 | ||||||||||||||
Interest expense, net | 15 | ||||||||||||||
Income (loss) before income taxes | 5 | ||||||||||||||
Income taxes | 1 | ||||||||||||||
Net income (loss) | 5 | ||||||||||||||
Capital expenditures | 93 | ||||||||||||||
Atlantic City Electric Company [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 3 | 2 | |||||||||||||
Atlantic City Electric Company [Member] | Intersegment Eliminations [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 2 | ||||||||||||||
Atlantic City Electric Company [Member] | Intersegment Eliminations [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 1 | ||||||||||||||
Corporate and Other [Member] | Corporate, Non-Segment [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Competitive businesses electric revenues | [1],[10] | 0 | 0 | 0 | |||||||||||
Competitive businesses natural gas revenues | [1],[10] | 0 | 0 | 0 | |||||||||||
Competitive businesses other revenues | [1],[10] | 0 | 0 | 0 | |||||||||||
Rate-regulated electric revenues | [1],[10] | 0 | 0 | 0 | |||||||||||
Rate-regulated natural gas revenues | [1],[10] | 0 | 0 | 0 | |||||||||||
Shared service and other revenues | [1],[10] | 1,948 | 1,831 | 1,648 | |||||||||||
Revenues | [1],[10] | 1,948 | 1,831 | 1,648 | |||||||||||
Depreciation and amortization | [10] | 92 | 87 | 74 | |||||||||||
Operating Expenses | [1],[10] | 1,929 | 1,742 | 1,812 | |||||||||||
Interest expense, net | [10] | 279 | 283 | 290 | |||||||||||
Income (loss) before income taxes | [10] | (249) | (296) | (555) | |||||||||||
Income taxes | [10] | (55) | 294 | (156) | |||||||||||
Net income (loss) | [10] | (193) | (590) | (398) | |||||||||||
Capital expenditures | [10] | 43 | 65 | 113 | |||||||||||
Assets | [10] | 8,355 | 8,618 | 8,355 | 8,618 | ||||||||||
Corporate and Other [Member] | Corporate, Non-Segment [Member] | Pepco Holdings LLC [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7],[11] | 0 | 0 | ||||||||||||
Rate-regulated natural gas revenues | [7],[11] | 0 | 0 | ||||||||||||
Shared service and other revenues | [7],[11] | 435 | 52 | ||||||||||||
Revenues | [7],[11] | 435 | 52 | ||||||||||||
Depreciation and amortization | [11] | 37 | 42 | ||||||||||||
Operating Expenses | [11] | 442 | 68 | ||||||||||||
Interest expense, net | [11] | 11 | 13 | ||||||||||||
Income (loss) before income taxes | [11] | 388 | 377 | ||||||||||||
Income taxes | [11] | (10) | 15 | ||||||||||||
Net income (loss) | [11] | (22) | (91) | ||||||||||||
Capital expenditures | [11] | 20 | 28 | ||||||||||||
Assets | [11] | $ 10,819 | $ 10,600 | 10,819 | 10,600 | ||||||||||
Corporate and Other [Member] | Corporate, Non-Segment [Member] | Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7],[11] | 5 | |||||||||||||
Rate-regulated natural gas revenues | [7],[11] | 0 | |||||||||||||
Shared service and other revenues | [7],[11] | 45 | |||||||||||||
Revenues | [7],[11] | 50 | |||||||||||||
Depreciation and amortization | [11] | 43 | |||||||||||||
Operating Expenses | [11] | 33 | |||||||||||||
Interest expense, net | [11] | 12 | |||||||||||||
Income (loss) before income taxes | [11] | (84) | |||||||||||||
Income taxes | [11] | (23) | |||||||||||||
Net income (loss) | [11] | (34) | |||||||||||||
Capital expenditures | [11] | 24 | |||||||||||||
Corporate and Other [Member] | Corporate, Non-Segment [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Rate-regulated electric revenues | [7],[11] | 42 | |||||||||||||
Rate-regulated natural gas revenues | [7],[11] | 1 | |||||||||||||
Shared service and other revenues | [7],[11] | 0 | |||||||||||||
Revenues | [7],[11] | 43 | |||||||||||||
Depreciation and amortization | [11] | 11 | |||||||||||||
Operating Expenses | [11] | 73 | |||||||||||||
Interest expense, net | [11] | 11 | |||||||||||||
Income (loss) before income taxes | [11] | 59 | |||||||||||||
Income taxes | [11] | (16) | |||||||||||||
Net income (loss) | [11] | (44) | |||||||||||||
Capital expenditures | [11] | 11 | |||||||||||||
Corporate and Other [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [6],[10] | 1,942 | 1,824 | 1,647 | |||||||||||
Corporate and Other [Member] | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [11] | 435 | 53 | ||||||||||||
Corporate and Other [Member] | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | Successor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [11] | $ 47 | |||||||||||||
Corporate and Other [Member] | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member] | Predecessor [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [11] | $ 0 | |||||||||||||
Generation Mid Atlantic [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Revenues | 5,487 | 5,540 | 6,179 | ||||||||||||
Generation Mid Atlantic [Member] | Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Revenues | [12] | 5,474 | 5,515 | 6,212 | |||||||||||
Generation Mid Atlantic [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | 13 | 25 | (33) | ||||||||||||
Generation Midwest [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Revenues | 4,706 | 4,181 | 4,412 | ||||||||||||
Generation Midwest [Member] | Operating Segments [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Revenues | [12] | 4,717 | 4,206 | 4,402 | |||||||||||
Generation Midwest [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | (11) | (25) | 10 | ||||||||||||
Segment Elimination [Member] | Intersegment Eliminations [Member] | |||||||||||||||
Segment Reporting Information [Line Items] | |||||||||||||||
Operating revenues from affiliates | [6] | $ (3,289) | $ (3,020) | $ (3,159) | |||||||||||
[1] | Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 23 — Supplemental Financial Information for additional information on total utility taxes. | ||||||||||||||
[2] | Exelon’s consolidated assets include $9,667 million and $9,597 million at December 31, 2018 and 2017, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,548 million and $3,618 million at December 31, 2018 and 2017, respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 2–Variable Interest Entities for additional information. | ||||||||||||||
[3] | PHI’s consolidated total assets include $33 million and $41 million at December 31, 2018 and 2017, respectively, of PHI's consolidated VIE that can only be used to settle the liabilities of the VIE. PHI’s consolidated total liabilities include $69 million and $102 million at December 31, 2018 and 2017, respectively, of PHI's consolidated VIE for which the VIE creditors do not have recourse to PHI. See Note 2 - Variable Interest Entities for additional information. | ||||||||||||||
[4] | Generation’s consolidated assets include $9,634 million and $9,556 million at December 31, 2018 and 2017, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,480 million and $3,516 million at December 31, 2018 and 2017, respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 2–Variable Interest Entities for additional information. | ||||||||||||||
[5] | Includes operating revenues from affiliates of $47 million and $43 million at PHI in 2017 and 2016, respectively. | ||||||||||||||
[6] | Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory authoritative guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. | ||||||||||||||
[7] | Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 23 — Supplemental Financial Information for additional information on total utility taxes. | ||||||||||||||
[8] | See Note 25 — Related Party Transactions for additional information on intersegment revenues. | ||||||||||||||
[9] | Amounts included represent activity for PHI's successor period, March 24, 2016 through December 31, 2018. | ||||||||||||||
[10] | Other primarily includes Exelon’s corporate operations, shared service entities and other financing and investment activities. | ||||||||||||||
[11] | Other primarily includes PHI’s corporate operations, shared service entities and other financing and investment activities. For the predecessor periods presented, Other includes the activity of PHI’s unregulated businesses which were distributed to Exelon and Generation as a result of the PHI Merger. | ||||||||||||||
[12] | Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants |
Segment Information Segment I_3
Segment Information Segment Information - Generation Total Revenues (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | ||||||||||
Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2017 | Jun. 30, 2017 | Mar. 31, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | $ 8,814 | $ 9,403 | $ 8,076 | $ 9,693 | $ 8,384 | $ 8,768 | $ 7,665 | $ 8,747 | $ 35,985 | $ 33,565 | $ 31,366 | |
Revenue from Related Parties | 0 | 0 | ||||||||||
Generation Mid Atlantic [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | 5,487 | 5,540 | 6,179 | |||||||||
Generation Midwest [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | 4,706 | 4,181 | 4,412 | |||||||||
Generation New England [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | 2,841 | 2,002 | 1,769 | |||||||||
Generation New York [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | 1,687 | 1,550 | 1,166 | |||||||||
Generation ERCOT [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | 1,133 | 962 | 837 | |||||||||
Generation Other Regions [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | 1,494 | 1,049 | 907 | |||||||||
Generation Reportable Segments Total [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | 17,348 | 15,284 | 15,270 | |||||||||
Generation Natural Gas [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | 2,780 | 2,628 | 2,281 | |||||||||
Generation All Other Segments [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [1] | 309 | 588 | 206 | ||||||||
Unrealized Gain (Loss) on Securities | (262) | (131) | (500) | |||||||||
Generation Total Consolidated Group [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | 20,437 | 18,500 | 17,757 | |||||||||
Operating Segments [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [2] | 35,985 | 33,567 | 31,365 | ||||||||
Operating Segments [Member] | Generation Mid Atlantic [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 5,474 | 5,515 | 6,212 | ||||||||
Operating Segments [Member] | Generation Midwest [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 4,717 | 4,206 | 4,402 | ||||||||
Operating Segments [Member] | Generation New England [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 2,845 | 2,010 | 1,778 | ||||||||
Operating Segments [Member] | Generation New York [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 1,687 | 1,567 | 1,208 | ||||||||
Operating Segments [Member] | Generation ERCOT [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 1,132 | 958 | 831 | ||||||||
Operating Segments [Member] | Generation Other Regions [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 1,556 | 1,076 | 969 | ||||||||
Operating Segments [Member] | Generation Reportable Segments Total [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 17,411 | 15,332 | 15,400 | ||||||||
Operating Segments [Member] | Generation Natural Gas [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 2,718 | 2,575 | 2,146 | ||||||||
Operating Segments [Member] | Generation All Other Segments [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Amortization of intangible assets related to commodity contracts | (38) | 52 | ||||||||||
Unrealized Gain (Loss) on Securities | (319) | (175) | (41) | |||||||||
Operating Segments [Member] | Generation Total Consolidated Group [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 20,437 | 18,500 | 17,757 | ||||||||
Corporate, Non-Segment [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | (1) | 7 | 10 | |||||||||
Corporate, Non-Segment [Member] | Generation All Other Segments [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [1],[3] | 308 | 593 | 211 | ||||||||
Intersegment Eliminations [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [2] | (3,294) | (3,025) | (3,164) | ||||||||
Revenue from Related Parties | [4] | 1 | 2 | 5 | ||||||||
Intersegment Eliminations [Member] | Generation Mid Atlantic [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | 13 | 25 | (33) | |||||||||
Intersegment Eliminations [Member] | Generation Midwest [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | (11) | (25) | 10 | |||||||||
Intersegment Eliminations [Member] | Generation New England [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | (4) | (8) | (9) | |||||||||
Intersegment Eliminations [Member] | Generation New York [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | 0 | (17) | (42) | |||||||||
Intersegment Eliminations [Member] | Generation ERCOT [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | 1 | 4 | 6 | |||||||||
Intersegment Eliminations [Member] | Generation Other Regions [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | (62) | (27) | (62) | |||||||||
Intersegment Eliminations [Member] | Generation Reportable Segments Total [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | (63) | (48) | (130) | |||||||||
Intersegment Eliminations [Member] | Generation Natural Gas [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | 62 | 53 | 135 | |||||||||
Intersegment Eliminations [Member] | Generation All Other Segments [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | [1] | 1 | (5) | (5) | ||||||||
Intersegment Eliminations [Member] | Generation Total Consolidated Group [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenue from Related Parties | 0 | 0 | 0 | |||||||||
Contracts with Customers [Member] | Operating Segments [Member] | Generation Mid Atlantic [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 5,241 | 5,523 | 6,182 | ||||||||
Contracts with Customers [Member] | Operating Segments [Member] | Generation Midwest [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 4,527 | 3,923 | 4,007 | ||||||||
Contracts with Customers [Member] | Operating Segments [Member] | Generation New England [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 2,660 | 2,064 | 1,953 | ||||||||
Contracts with Customers [Member] | Operating Segments [Member] | Generation New York [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 1,723 | 1,605 | 1,198 | ||||||||
Contracts with Customers [Member] | Operating Segments [Member] | Generation ERCOT [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 572 | 641 | 810 | ||||||||
Contracts with Customers [Member] | Operating Segments [Member] | Generation Other Regions [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 870 | 594 | 670 | ||||||||
Contracts with Customers [Member] | Operating Segments [Member] | Generation Reportable Segments Total [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 15,593 | 14,350 | 14,820 | ||||||||
Contracts with Customers [Member] | Operating Segments [Member] | Generation Natural Gas [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 1,524 | 1,658 | 1,953 | ||||||||
Contracts with Customers [Member] | Operating Segments [Member] | Generation Total Consolidated Group [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3] | 17,627 | 16,752 | 17,529 | ||||||||
Contracts with Customers [Member] | Corporate, Non-Segment [Member] | Generation All Other Segments [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [1],[3] | 510 | 744 | 756 | ||||||||
Other [Member] | Operating Segments [Member] | Generation Mid Atlantic [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3],[5] | 233 | (8) | 30 | ||||||||
Other [Member] | Operating Segments [Member] | Generation Midwest [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3],[5] | 190 | 283 | 395 | ||||||||
Other [Member] | Operating Segments [Member] | Generation New England [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3],[5] | 185 | (54) | (175) | ||||||||
Other [Member] | Operating Segments [Member] | Generation New York [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3],[5] | (36) | (38) | 10 | ||||||||
Other [Member] | Operating Segments [Member] | Generation ERCOT [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3],[5] | 560 | 317 | 21 | ||||||||
Other [Member] | Operating Segments [Member] | Generation Other Regions [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3],[5] | 686 | 482 | 299 | ||||||||
Other [Member] | Operating Segments [Member] | Generation Reportable Segments Total [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3],[5] | 1,818 | 982 | 580 | ||||||||
Other [Member] | Operating Segments [Member] | Generation Natural Gas [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3],[5] | 1,194 | 917 | 193 | ||||||||
Other [Member] | Operating Segments [Member] | Generation Total Consolidated Group [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [3],[5] | 2,810 | 1,748 | 228 | ||||||||
Other [Member] | Corporate, Non-Segment [Member] | Generation All Other Segments [Member] | ||||||||||||
Segment Reporting Information [Line Items] | ||||||||||||
Revenues | [1],[3],[5] | $ (202) | $ (151) | $ (545) | ||||||||
[1] | Other represents activities not allocated to a region. See text above for a description of included activities. Includes a $38 million and $52 million decrease to revenues for the amortization of intangible assets and liabilities related to commodity contracts recorded at fair value in 2017 and 2016, respectively, unrealized mark-to-market losses of $262 million, $131 million, and $500 million in 2018, 2017, and 2016, respectively, and elimination of intersegment revenues. | |||||||||||
[2] | Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 23 — Supplemental Financial Information for additional information on total utility taxes. | |||||||||||
[3] | Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants | |||||||||||
[4] | Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory authoritative guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. | |||||||||||
[5] | Includes revenues from derivatives and leases. |
Segment Information Segment I_4
Segment Information Segment Information - Generation Total Revenues Net of Purchased Power and Fuel Expense (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | $ 3,073 | $ 3,214 | $ 3,317 | |
Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 3,135 | 2,820 | 2,971 | |
Generation New England [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 354 | 514 | 438 | |
Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 1,122 | 1,008 | 752 | |
Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 258 | 332 | 281 | |
Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 375 | 305 | 336 | |
Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 8,317 | 8,193 | 8,095 | |
Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | [1] | 427 | 617 | 832 |
Unrealized Gain (Loss) on Securities | (262) | (131) | (500) | |
Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Revenue Net of Purchase Power And Fuel | 8,744 | 8,810 | 8,927 | |
Operating Segments [Member] | Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
RNF from external customers | [2] | 3,022 | 3,105 | 3,282 |
Operating Segments [Member] | Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
RNF from external customers | [2] | 3,112 | 2,810 | 2,969 |
Operating Segments [Member] | Generation New England [Member] | ||||
Segment Reporting Information [Line Items] | ||||
RNF from external customers | [2] | 368 | 538 | 467 |
Operating Segments [Member] | Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
RNF from external customers | [2] | 1,112 | 1,007 | 771 |
Operating Segments [Member] | Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
RNF from external customers | [2] | 501 | 575 | 412 |
Operating Segments [Member] | Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
RNF from external customers | [2] | 515 | 476 | 483 |
Operating Segments [Member] | Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
RNF from external customers | [2] | 8,630 | 8,511 | 8,384 |
Operating Segments [Member] | Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
RNF from external customers | [1],[2] | 114 | 299 | 543 |
Amortization Of Intangible Assets Related To Commodity Contracts For Revenue Net Purchased Power And Fuel | 54 | 57 | ||
Unrealized Gain (Loss) on Securities | (319) | (175) | (41) | |
Nuclear Fuel Amortization | (57) | (12) | (60) | |
Operating Segments [Member] | Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
RNF from external customers | [2] | 8,744 | 8,810 | 8,927 |
Intersegment Eliminations [Member] | Generation Mid Atlantic [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | 51 | 109 | 35 | |
Intersegment Eliminations [Member] | Generation Midwest [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | 23 | 10 | 2 | |
Intersegment Eliminations [Member] | Generation New England [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | (14) | (24) | (29) | |
Intersegment Eliminations [Member] | Generation New York [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | 10 | 1 | (19) | |
Intersegment Eliminations [Member] | Generation ERCOT [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | (243) | (243) | (131) | |
Intersegment Eliminations [Member] | Generation Other Regions [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | (140) | (171) | (147) | |
Intersegment Eliminations [Member] | Generation Reportable Segments Total [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | (313) | (318) | (289) | |
Intersegment Eliminations [Member] | Generation All Other Segments [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | [1] | 313 | 318 | 289 |
Intersegment Eliminations [Member] | Generation Total Consolidated Group [Member] | ||||
Segment Reporting Information [Line Items] | ||||
Intersegment Revenue Net Of Purchase Power And Fuel | $ 0 | $ 0 | $ 0 | |
[1] | Other represents activities not allocated to a region. See text above for a description of included activities. Includes a $54 million and $57 million decrease in RNF for the amortization of intangible assets and liabilities related to commodity contracts in 2017 and 2016, respectively, unrealized mark-to-market losses of $319 million, $175 million, and $41 million in 2018, 2017, and 2016, respectively, accelerated nuclear fuel amortization associated with the announced early plant retirements as discussed in Note 8 - Early Plant Retirements of $57 million, $12 million and $60 million for the year ended December 31, 2018, 2017, and 2016 and the elimination of intersegment RNF. | |||
[2] | Includes purchases and sales from/to third parties and affiliated sales to the Utility Registrants. |
Segment Information Segment I_5
Segment Information Segment Information - Electric and Gas Revenue by Customer Class (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||||||||||
Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2017 | Jun. 30, 2017 | Mar. 31, 2017 | Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | $ 0 | $ 0 | ||||||||||||
Electric operating revenues | 0 | 0 | ||||||||||||
Natural gas operating revenues | 0 | 0 | ||||||||||||
Revenues | $ 8,814 | $ 9,403 | $ 8,076 | $ 9,693 | $ 8,384 | $ 8,768 | $ 7,665 | $ 8,747 | $ 35,985 | 33,565 | 31,366 | |||
Revenues from alternative revenue programs | (62) | 207 | 48 | |||||||||||
Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [1] | 15,344 | 14,840 | 13,869 | ||||||||||
Natural gas operating revenues | [1] | 1,470 | 1,333 | 1,166 | ||||||||||
Revenues | [1] | 35,985 | 33,567 | 31,365 | ||||||||||
Operating Segments [Member] | Pepco Holdings LLC [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [1],[2],[3] | 4,609 | 4,469 | |||||||||||
Natural gas operating revenues | [1],[2],[3] | 181 | 161 | |||||||||||
Revenues | [1],[2],[3] | 4,805 | 4,679 | |||||||||||
Commonwealth Edison Co [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 27 | 15 | 15 | |||||||||||
Electric operating revenues | 5,884 | 5,478 | 5,263 | |||||||||||
Natural gas operating revenues | 0 | 0 | ||||||||||||
Revenues | 1,373 | 1,598 | 1,398 | 1,512 | 1,309 | 1,571 | 1,357 | 1,298 | 5,882 | 5,536 | 5,254 | |||
Revenues from alternative revenue programs | (29) | 43 | (24) | |||||||||||
Commonwealth Edison Co [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | [4] | 0 | 0 | |||||||||||
Revenues from alternative revenue programs | (29) | 43 | (24) | |||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Electric Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [5] | 5,881 | 5,463 | 5,248 | ||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Electric Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 2,942 | 2,715 | 2,603 | |||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Electric Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 1,487 | 1,363 | 1,318 | |||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Electric Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 538 | 455 | 462 | |||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Electric Revenues [Member] | Public Authorities & Electric Railroads [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 47 | 44 | 45 | |||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Electric Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [6] | 867 | 886 | 820 | ||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Electric Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [7] | 30 | 30 | 30 | ||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [8] | 0 | 0 | 0 | ||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | 0 | |||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | |||||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | 0 | |||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [9] | 0 | 0 | 0 | ||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Transportation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | 0 | |||||||||||
Commonwealth Edison Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [7] | 0 | 0 | 0 | ||||||||||
Commonwealth Edison Co [Member] | Regulated Operation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 5,881 | 5,463 | 5,248 | |||||||||||
Commonwealth Edison Co [Member] | Other Regulated Revenue [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 1 | 73 | 6 | |||||||||||
PECO Energy Co [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 8 | 7 | 8 | |||||||||||
Electric operating revenues | 2,469 | 2,369 | 2,524 | |||||||||||
Natural gas operating revenues | 568 | 494 | 462 | |||||||||||
Revenues | 765 | 757 | 653 | 866 | 729 | 715 | 630 | 796 | 3,038 | 2,870 | 2,994 | |||
Revenues from alternative revenue programs | (7) | 0 | 0 | |||||||||||
PECO Energy Co [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | [4] | 0 | 0 | |||||||||||
Revenues from alternative revenue programs | (7) | 0 | 0 | |||||||||||
PECO Energy Co [Member] | Rate-Regulated Electric Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [5] | 2,464 | 2,363 | 2,519 | ||||||||||
PECO Energy Co [Member] | Rate-Regulated Electric Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 1,566 | 1,505 | 1,631 | |||||||||||
PECO Energy Co [Member] | Rate-Regulated Electric Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 404 | 401 | 430 | |||||||||||
PECO Energy Co [Member] | Rate-Regulated Electric Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 223 | 223 | 234 | |||||||||||
PECO Energy Co [Member] | Rate-Regulated Electric Revenues [Member] | Public Authorities & Electric Railroads [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 28 | 30 | 32 | |||||||||||
PECO Energy Co [Member] | Rate-Regulated Electric Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [6] | 243 | 204 | 192 | ||||||||||
PECO Energy Co [Member] | Rate-Regulated Electric Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [7] | 12 | 12 | 12 | ||||||||||
PECO Energy Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [8] | 568 | 494 | 463 | ||||||||||
PECO Energy Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 395 | 331 | 309 | |||||||||||
PECO Energy Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 143 | 131 | 121 | |||||||||||
PECO Energy Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 1 | 1 | 0 | |||||||||||
PECO Energy Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [9] | 6 | 8 | 9 | ||||||||||
PECO Energy Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Transportation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 23 | 23 | 24 | |||||||||||
PECO Energy Co [Member] | Rate-Regulated Natural Gas Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [7] | 1 | 1 | 0 | ||||||||||
PECO Energy Co [Member] | Regulated Operation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 3,032 | 2,857 | 2,982 | |||||||||||
PECO Energy Co [Member] | Other Regulated Revenue [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 6 | 13 | 12 | |||||||||||
Baltimore Gas and Electric Company [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 29 | 16 | 21 | |||||||||||
Electric operating revenues | 2,428 | 2,384 | 2,531 | |||||||||||
Natural gas operating revenues | 738 | 652 | 628 | |||||||||||
Revenues | 799 | 731 | 662 | 977 | 813 | 738 | 674 | 951 | 3,169 | 3,176 | 3,233 | |||
Revenues from alternative revenue programs | (26) | 124 | 53 | |||||||||||
Baltimore Gas and Electric Company [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | [4] | 0 | 0 | |||||||||||
Revenues from alternative revenue programs | (26) | 124 | 53 | |||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 8 | 5 | 7 | |||||||||||
Electric operating revenues | [5] | 2,423 | 2,376 | 2,525 | ||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 1,382 | 1,365 | 1,504 | |||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 257 | 254 | 276 | |||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 429 | 427 | 434 | |||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Public Authorities & Electric Railroads [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 28 | 31 | 35 | |||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [6] | 327 | 299 | 276 | ||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [7] | 13 | 13 | 13 | ||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 21 | 11 | 14 | |||||||||||
Natural gas operating revenues | [8] | 755 | 659 | 640 | ||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 491 | 437 | 432 | |||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 77 | 75 | 66 | |||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 124 | 119 | 114 | |||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [9] | 63 | 28 | 28 | ||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Transportation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | 0 | |||||||||||
Baltimore Gas and Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [7] | 4 | 4 | 2 | ||||||||||
Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 3,178 | 3,035 | 3,165 | |||||||||||
Baltimore Gas and Electric Company [Member] | Other Regulated Revenue [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | (9) | 141 | 68 | |||||||||||
Pepco Holdings LLC [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 15 | 50 | ||||||||||||
Electric operating revenues | 4,609 | 4,428 | ||||||||||||
Natural gas operating revenues | 181 | 161 | ||||||||||||
Revenues | 1,117 | 1,361 | 1,076 | 1,251 | 1,121 | 1,310 | 1,074 | 1,175 | 4,805 | 4,679 | ||||
Revenues from alternative revenue programs | 0 | 40 | ||||||||||||
Pepco Holdings LLC [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | [4] | 47 | ||||||||||||
Revenues from alternative revenue programs | 0 | 40 | ||||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 3 | 2 | ||||||||||||
Electric operating revenues | [5] | 4,614 | 4,423 | |||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 2,351 | 2,246 | ||||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 488 | 490 | ||||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 1,124 | 1,086 | ||||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Public Authorities & Electric Railroads [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 58 | 60 | ||||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [6] | 593 | 541 | |||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [7] | 10 | 8 | |||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [8] | 180 | 160 | |||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 99 | 90 | ||||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 44 | 38 | ||||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 8 | 8 | ||||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [9] | 13 | 9 | |||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Transportation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 16 | 15 | ||||||||||||
Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [7] | 1 | 1 | |||||||||||
Pepco Holdings LLC [Member] | Regulated Operation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 4,794 | 4,583 | ||||||||||||
Pepco Holdings LLC [Member] | Other Regulated Revenue [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 15 | |||||||||||||
Revenues | 11 | 96 | ||||||||||||
Potomac Electric Power Company [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 6 | 6 | 5 | |||||||||||
Electric operating revenues | 2,233 | 2,126 | 2,167 | |||||||||||
Natural gas operating revenues | 0 | 0 | ||||||||||||
Revenues | 531 | 628 | 523 | 557 | 510 | 604 | 514 | 530 | 2,239 | 2,158 | 2,186 | |||
Revenues from alternative revenue programs | 0 | 26 | 14 | |||||||||||
Potomac Electric Power Company [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | [4] | 0 | 0 | |||||||||||
Revenues from alternative revenue programs | 0 | 26 | 14 | |||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Electric Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [5] | 2,232 | 2,127 | 2,166 | ||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Electric Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 1,021 | 964 | 1,004 | |||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Electric Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 140 | 137 | 150 | |||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Electric Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 846 | 794 | 790 | |||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Electric Revenues [Member] | Public Authorities & Electric Railroads [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 32 | 33 | 32 | |||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Electric Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [6] | 193 | 199 | 190 | ||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Electric Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [7] | 7 | 5 | 6 | ||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [8] | 0 | 0 | 0 | ||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | 0 | |||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | ||||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | 0 | |||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [9] | 0 | 0 | 0 | ||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Transportation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | 0 | |||||||||||
Potomac Electric Power Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [7] | 0 | 0 | 0 | ||||||||||
Potomac Electric Power Company [Member] | Regulated Operation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 2,232 | 2,127 | 2,166 | |||||||||||
Potomac Electric Power Company [Member] | Other Regulated Revenue [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 7 | 31 | 20 | |||||||||||
Delmarva Power & Light Company [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 8 | 8 | 7 | |||||||||||
Electric operating revenues | 1,139 | 1,125 | 1,128 | |||||||||||
Natural gas operating revenues | 181 | 161 | 148 | |||||||||||
Revenues | 331 | 328 | 289 | 384 | 330 | 327 | 282 | 362 | 1,332 | 1,300 | 1,277 | |||
Revenues from alternative revenue programs | 4 | 6 | (6) | |||||||||||
Delmarva Power & Light Company [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | [4] | 0 | 0 | |||||||||||
Revenues from alternative revenue programs | 4 | 6 | (6) | |||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Electric Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [5] | 1,144 | 1,130 | 1,132 | ||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Electric Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 669 | 663 | 672 | |||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Electric Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 186 | 187 | 188 | |||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Electric Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 100 | 103 | 99 | |||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Electric Revenues [Member] | Public Authorities & Electric Railroads [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 14 | 14 | 13 | |||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Electric Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [6] | 175 | 163 | 160 | ||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Electric Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [7] | 3 | 3 | 3 | ||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [8] | 180 | 160 | 148 | ||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 99 | 90 | 86 | |||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 44 | 38 | 35 | |||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 8 | 8 | 6 | |||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [9] | 13 | 9 | 8 | ||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Transportation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 16 | 15 | 13 | |||||||||||
Delmarva Power & Light Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [7] | 1 | 1 | 0 | ||||||||||
Delmarva Power & Light Company [Member] | Regulated Operation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 1,324 | 1,290 | 1,280 | |||||||||||
Delmarva Power & Light Company [Member] | Other Regulated Revenue [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 8 | 10 | (3) | |||||||||||
Atlantic City Electric Company [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 3 | 2 | 3 | |||||||||||
Electric operating revenues | 1,237 | 1,176 | 1,245 | |||||||||||
Natural gas operating revenues | 0 | 0 | ||||||||||||
Revenues | $ 254 | $ 406 | $ 265 | $ 310 | $ 271 | $ 370 | $ 270 | $ 275 | 1,236 | 1,186 | 1,257 | |||
Revenues from alternative revenue programs | (4) | 8 | 9 | |||||||||||
Atlantic City Electric Company [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | [4] | 0 | 0 | |||||||||||
Revenues from alternative revenue programs | (4) | 8 | 9 | |||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [5] | 1,240 | 1,178 | 1,248 | ||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 661 | 619 | 664 | |||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 162 | 166 | 183 | |||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 178 | 189 | 201 | |||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Public Authorities & Electric Railroads [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 12 | 13 | 13 | |||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [6] | 227 | 191 | 187 | ||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Electric Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [7] | 0 | 0 | 0 | ||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [8] | 0 | 0 | 0 | ||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | 0 | |||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | ||||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | 0 | |||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [9] | 0 | 0 | 0 | ||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Transportation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 0 | 0 | 0 | |||||||||||
Atlantic City Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [7] | 0 | 0 | 0 | ||||||||||
Atlantic City Electric Company [Member] | Regulated Operation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 1,240 | 1,178 | 1,248 | |||||||||||
Atlantic City Electric Company [Member] | Other Regulated Revenue [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | (4) | 8 | $ 9 | |||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | $ 3,643 | |||||||||||||
Successor [Member] | Operating Segments [Member] | Pepco Holdings LLC [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [1],[2],[3] | 3,506 | ||||||||||||
Natural gas operating revenues | [1],[2],[3] | 92 | ||||||||||||
Revenues | [1],[2],[3] | 3,643 | ||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 45 | $ 15 | 50 | |||||||||||
Electric operating revenues | 3,463 | 4,428 | ||||||||||||
Natural gas operating revenues | 92 | 161 | ||||||||||||
Revenues | 3,643 | 4,679 | ||||||||||||
Revenues from alternative revenue programs | 43 | $ 40 | ||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | [4] | 43 | ||||||||||||
Revenues from alternative revenue programs | 43 | |||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [5] | 3,459 | ||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 1,779 | |||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 400 | |||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 835 | |||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Public Authorities & Electric Railroads [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 45 | |||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [6] | 400 | ||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [7] | 6 | ||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [8] | 92 | ||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 50 | |||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 21 | |||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 4 | |||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [9] | 7 | ||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Transportation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 10 | |||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [7] | 0 | ||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 3,551 | |||||||||||||
Successor [Member] | Pepco Holdings LLC [Member] | Other Regulated Revenue [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | $ 92 | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | $ 1,153 | |||||||||||||
Predecessor [Member] | Operating Segments [Member] | Pepco Holdings LLC [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [3] | 1,096 | ||||||||||||
Natural gas operating revenues | [3] | 57 | ||||||||||||
Revenues | [3] | 1,153 | ||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Operating revenues from affiliates | 0 | |||||||||||||
Electric operating revenues | 1,122 | |||||||||||||
Natural gas operating revenues | 57 | |||||||||||||
Revenues | 1,153 | |||||||||||||
Revenues from alternative revenue programs | (26) | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | [4] | 0 | ||||||||||||
Revenues from alternative revenue programs | (26) | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [5] | 1,119 | ||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 561 | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 121 | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 255 | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Public Authorities & Electric Railroads [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | 13 | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [6] | 169 | ||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Electric Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Electric operating revenues | [7] | 3 | ||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [8] | 57 | ||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Residential [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 36 | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Small Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 14 | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Large Commercial & Industrial [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 2 | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Other [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [9] | 2 | ||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Transportation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | 3 | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Rate-Regulated Natural Gas Revenues [Member] | Operating Segments [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Natural gas operating revenues | [7] | 0 | ||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | 1,176 | |||||||||||||
Predecessor [Member] | Pepco Holdings LLC [Member] | Other Regulated Revenue [Member] | ||||||||||||||
Revenue, Major Customer [Line Items] | ||||||||||||||
Revenues | $ (23) | |||||||||||||
[1] | Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 23 — Supplemental Financial Information for additional information on total utility taxes. | |||||||||||||
[2] | Amounts included represent activity for PHI's successor period, March 24, 2016 through December 31, 2018. | |||||||||||||
[3] | Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 23 — Supplemental Financial Information for additional information on total utility taxes. | |||||||||||||
[4] | Includes operating revenues from affiliates of $47 million and $43 million at PHI in 2017 and 2016, respectively. | |||||||||||||
[5] | Includes operating revenues from affiliates of $27 million, $7 million, $8 million, $15 million, $6 million, $8 million and $3 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2018, $15 million, $6 million, $5 million, $3 million, $6 million, $8 million and $2 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, in 2017, and $15 million, $7 million, $7 million, $2 million, $5 million, $7 million and $3 million at ComEd, PECO, BGE, PHI, Pepco, DPL and ACE, respectively, in 2016. | |||||||||||||
[6] | Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue. | |||||||||||||
[7] | Includes late payment charge revenues. | |||||||||||||
[8] | Includes operating revenues from affiliates of $1 million and $21 million at PECO and BGE, respectively, in 2018, $1 million and $11 million at PECO and BGE, respectively, in 2017, and $1 million and $14 million at PECO and BGE, respectively, in 2016. | |||||||||||||
[9] | Includes revenues from off-system natural gas sales. |
Related Party Transactions - Re
Related Party Transactions - Related Party Transactions included in Consolidated Income Statement (Details) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | |||
Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | $ 0 | $ 0 | |||
Interest expense to affiliates, net | $ 25 | 36 | 41 | ||
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions | (28) | (32) | (24) | ||
Equity in earnings (losses) of unconsolidated affiliates | (28) | (32) | (24) | ||
Cash dividends paid to parent | 1,332 | 1,236 | 1,166 | ||
Corporate, Non-Segment [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | (1) | 7 | 10 | ||
Exelon Generation Co LLC Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [1] | (2) | 0 | ||
PECO Energy Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [1] | 0 | 1 | 1 | |
Baltimore Gas And Electric Company Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [1] | 0 | 4 | 4 | |
Atlantic City Electric Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [1] | 0 | 0 | 0 | |
ComEd Financing III Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | 13 | 14 | 13 | ||
PECO Trust III Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | 6 | 6 | 6 | ||
PECO Trust IV Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | 6 | 6 | 6 | ||
BGE Capital Trust II Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | 0 | 10 | 16 | ||
Qualifying Facilities And Domestic Power Projects Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions | (29) | (33) | (25) | ||
Other Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 2 | 5 | ||
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions | 1 | 1 | 1 | ||
Exelon Generation Co L L C [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1,268 | 1,115 | 1,439 | ||
Related Party Transaction, Purchases from Related Party | 14 | 19 | 12 | ||
Operating and maintenance from affiliates | 661 | 697 | 663 | ||
Interest expense to affiliates, net | 36 | 39 | 39 | ||
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions | (30) | (33) | (25) | ||
Equity in earnings (losses) of unconsolidated affiliates | (30) | (33) | (25) | ||
Cash distribution paid to member | 1,001 | 659 | 922 | ||
Cash contributions received from affiliates | 155 | 102 | 142 | ||
Exelon Generation Co L L C [Member] | Commonwealth Edison Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [2] | 523 | 121 | 47 | |
Related Party Transaction, Purchases from Related Party | (6) | 13 | 0 | ||
Operating and maintenance from affiliates | [3] | 7 | 7 | 7 | |
Exelon Generation Co L L C [Member] | PECO Energy Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [4] | 128 | 138 | 290 | |
Operating and maintenance from affiliates | [3] | 2 | 1 | 3 | |
Interest expense to affiliates, net | 0 | 1 | 0 | ||
Exelon Generation Co L L C [Member] | Baltimore Gas And Electric Company Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [5] | 260 | 388 | 608 | |
Related Party Transaction, Purchases from Related Party | 20 | 9 | 12 | ||
Operating and maintenance from affiliates | [3] | 2 | 1 | 1 | |
Exelon Generation Co L L C [Member] | Potomac Electric Power Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [6] | 206 | 255 | 295 | |
Operating and maintenance from affiliates | 1 | 0 | 1 | ||
Exelon Generation Co L L C [Member] | Delmarva Power & Light Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [7] | 120 | 179 | 154 | |
Exelon Generation Co L L C [Member] | Atlantic City Electric Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [8] | 29 | 29 | 37 | |
Exelon Generation Co L L C [Member] | PHI Service Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating and maintenance from affiliates | 1 | 1 | 1 | ||
Exelon Generation Co L L C [Member] | Exelon Corporation Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | [9] | 36 | 37 | 39 | |
Cash distribution paid to member | 1,001 | 659 | 922 | ||
Cash contributions received from affiliates | 155 | 102 | 142 | ||
Exelon Generation Co L L C [Member] | Exelon Business Services Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 2 | 1 | 2 | ||
Operating and maintenance from affiliates | [10] | 652 | 689 | 650 | |
Capitalized costs | [10] | 67 | 98 | 98 | |
Exelon Generation Co L L C [Member] | Potomac Capital Investment Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | 0 | 1 | 0 | ||
Exelon Generation Co L L C [Member] | Qualifying Facilities And Domestic Power Projects Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions | (30) | (33) | (25) | ||
Exelon Generation Co L L C [Member] | Other Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 0 | 4 | 6 | ||
Related Party Transaction, Purchases from Related Party | 0 | (3) | 0 | ||
Operating and maintenance from affiliates | (4) | (2) | 0 | ||
Commonwealth Edison Co [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 27 | 15 | 15 | ||
Related Party Transaction, Purchases from Related Party | 529 | 108 | 47 | ||
Operating and maintenance from affiliates | 267 | 270 | 227 | ||
Interest expense to affiliates, net | 13 | 13 | 13 | ||
Equity in earnings (losses) of unconsolidated affiliates | 0 | 0 | 0 | ||
Cash dividends paid to parent | 459 | 422 | 369 | ||
Proceeds from Contributions from Parent | 500 | 651 | 315 | ||
Commonwealth Edison Co [Member] | Exelon Generation Co LLC Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 9 | 9 | 7 | ||
Related Party Transaction, Purchases from Related Party | [11] | 529 | 108 | 47 | |
Commonwealth Edison Co [Member] | PECO Energy Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 10 | 0 | 1 | ||
Operating and maintenance from affiliates | 1 | 0 | 1 | ||
Commonwealth Edison Co [Member] | Baltimore Gas And Electric Company Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 0 | 1 | ||
Operating and maintenance from affiliates | 1 | 0 | 1 | ||
Commonwealth Edison Co [Member] | Exelon Corporation Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Cash dividends paid to parent | 459 | 422 | 369 | ||
Proceeds from Contributions from Parent | 500 | 651 | 315 | ||
Commonwealth Edison Co [Member] | Exelon Business Services Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 7 | 6 | 6 | ||
Operating and maintenance from affiliates | [12] | 265 | 270 | 225 | |
Capitalized costs | [12] | 135 | 118 | 112 | |
Commonwealth Edison Co [Member] | ComEd Financing III Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | 13 | 13 | 13 | ||
PECO Energy Co [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 8 | 7 | 8 | ||
Related Party Transaction, Purchases from Related Party | 126 | 135 | 287 | ||
Operating and maintenance from affiliates | 156 | 149 | 146 | ||
Interest expense to affiliates, net | 14 | 11 | 12 | ||
Equity in earnings (losses) of unconsolidated affiliates | 0 | 0 | 0 | ||
Cash dividends paid to parent | 306 | 288 | 277 | ||
Proceeds from Contributions from Parent | 89 | 16 | 18 | ||
PECO Energy Co [Member] | Exelon Generation Co LLC Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [13] | 2 | 1 | 3 | |
Related Party Transaction, Purchases from Related Party | [14] | 126 | 135 | 287 | |
Operating and maintenance from affiliates | 2 | 2 | 2 | ||
Interest income from affiliates, net | 0 | (1) | 0 | ||
PECO Energy Co [Member] | Commonwealth Edison Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 0 | 1 | ||
Operating and maintenance from affiliates | 7 | 0 | 1 | ||
PECO Energy Co [Member] | Baltimore Gas And Electric Company Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 1 | 1 | ||
Operating and maintenance from affiliates | 1 | 1 | 1 | ||
PECO Energy Co [Member] | Atlantic City Electric Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 0 | 0 | ||
PECO Energy Co [Member] | Exelon Corporation Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | 2 | 0 | 0 | ||
Cash dividends paid to parent | 306 | 288 | 277 | ||
Proceeds from Contributions from Parent | 89 | 16 | 18 | ||
PECO Energy Co [Member] | Exelon Business Services Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 3 | 5 | 3 | ||
Operating and maintenance from affiliates | [15] | 146 | 146 | 142 | |
Capitalized costs | [15] | 64 | 59 | 57 | |
PECO Energy Co [Member] | PECO Trust III Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | 6 | 6 | 6 | ||
PECO Energy Co [Member] | PECO Trust IV Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | 6 | 6 | 6 | ||
Baltimore Gas and Electric Company [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 29 | 16 | 21 | ||
Related Party Transaction, Purchases from Related Party | 257 | 384 | 604 | ||
Operating and maintenance from affiliates | 162 | 153 | 132 | ||
Interest expense to affiliates, net | 0 | 10 | 16 | ||
Equity in earnings (losses) of unconsolidated affiliates | 0 | 0 | 0 | ||
Cash dividends paid to parent | 209 | 198 | 179 | ||
Proceeds from Contributions from Parent | 109 | 184 | 61 | ||
Baltimore Gas and Electric Company [Member] | Exelon Generation Co LLC Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [16] | 22 | 10 | 13 | |
Related Party Transaction, Purchases from Related Party | [17] | 257 | 384 | 604 | |
Operating and maintenance from affiliates | 3 | 0 | 0 | ||
Baltimore Gas and Electric Company [Member] | Commonwealth Edison Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 0 | 1 | ||
Operating and maintenance from affiliates | 1 | 0 | 1 | ||
Baltimore Gas and Electric Company [Member] | PECO Energy Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 1 | 1 | ||
Operating and maintenance from affiliates | 1 | 1 | 1 | ||
Baltimore Gas and Electric Company [Member] | Exelon Corporation Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Cash dividends paid to parent | 209 | 198 | 179 | ||
Proceeds from Contributions from Parent | 109 | 184 | 61 | ||
Baltimore Gas and Electric Company [Member] | Exelon Business Services Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 5 | 5 | 6 | ||
Operating and maintenance from affiliates | [18] | 157 | 152 | 130 | |
Capitalized costs | [18] | 79 | 54 | 36 | |
Baltimore Gas and Electric Company [Member] | BGE Capital Trust II Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Interest expense to affiliates, net | 0 | 10 | 16 | ||
Pepco Holdings LLC [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 15 | 50 | |||
Related Party Transaction, Purchases from Related Party | 355 | 463 | |||
Operating and maintenance from affiliates | 152 | 150 | |||
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions | 1 | 1 | |||
Equity in earnings (losses) of unconsolidated affiliates | 1 | 1 | |||
Cash distribution paid to member | 326 | 311 | |||
Proceeds from Contributions from Parent | 385 | 758 | |||
Pepco Holdings LLC [Member] | Successor [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | $ 45 | 15 | 50 | ||
Related Party Transaction, Purchases from Related Party | 486 | ||||
Operating and maintenance from affiliates | 89 | 152 | 150 | ||
Capitalized costs | 0 | 181 | 0 | ||
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions | 0 | ||||
Equity in earnings (losses) of unconsolidated affiliates | 0 | ||||
Cash distribution paid to member | 273 | ||||
Proceeds from Contributions from Parent | 1,251 | ||||
Pepco Holdings LLC [Member] | Exelon Generation Co LLC Affiliate [Member] | Successor [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 2 | 0 | ||
Related Party Transaction, Purchases from Related Party | 486 | 355 | 463 | ||
Pepco Holdings LLC [Member] | PHI Service Co Affiliate [Member] | Successor [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 0 | 1 | 2 | ||
Capitalized costs | [19] | 0 | 79 | 0 | |
Pepco Holdings LLC [Member] | Exelon Corporation Affiliate [Member] | Successor [Member] | |||||
Related Party Transaction [Line Items] | |||||
Cash dividends paid to parent | 1,251 | 326 | 311 | ||
Proceeds from Contributions from Parent | 273 | 385 | 758 | ||
Pepco Holdings LLC [Member] | Exelon Business Services Co Affiliate [Member] | Successor [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 44 | 12 | 48 | ||
Operating and maintenance from affiliates | [19] | 86 | 147 | 145 | |
Capitalized costs | [19] | 0 | 102 | 0 | |
Pepco Holdings LLC [Member] | Other Affiliate [Member] | Successor [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating and maintenance from affiliates | 3 | 5 | 5 | ||
Income (Loss) from Equity Method Investments, Net of Dividends or Distributions | $ 0 | 1 | 0 | ||
Potomac Electric Power Company [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 6 | 6 | 5 | ||
Related Party Transaction, Purchases from Related Party | 206 | 255 | 295 | ||
Operating and maintenance from affiliates | 226 | 58 | 35 | ||
Capitalized costs | 72 | 0 | 0 | ||
Equity in earnings (losses) of unconsolidated affiliates | 0 | 0 | 0 | ||
Cash dividends paid to parent | 169 | 133 | 136 | ||
Proceeds from Contributions from Parent | 166 | 161 | 187 | ||
Potomac Electric Power Company [Member] | Corporate, Non-Segment [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating and maintenance | 0 | 248 | 302 | ||
Potomac Electric Power Company [Member] | Exelon Generation Co LLC Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | [20] | 1 | 0 | 1 | |
Related Party Transaction, Purchases from Related Party | [21] | 206 | 255 | 295 | |
Potomac Electric Power Company [Member] | PHI Service Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 4 | 6 | 4 | ||
Operating and maintenance from affiliates | [22],[23] | 137 | 5 | 4 | |
Operating and maintenance | [22],[23] | 0 | 219 | 263 | |
Capitalized costs | [23] | 32 | 0 | 0 | |
Potomac Electric Power Company [Member] | Exelon Corporation Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Cash dividends paid to parent | 169 | 133 | 136 | ||
Proceeds from Contributions from Parent | 166 | 161 | 187 | ||
Potomac Electric Power Company [Member] | Exelon Business Services Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 0 | 0 | ||
Operating and maintenance from affiliates | [23] | 89 | 53 | 31 | |
Capitalized costs | [23] | 40 | 0 | 0 | |
Potomac Electric Power Company [Member] | Pepco Energy Services Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating and maintenance | [24] | 0 | 29 | 39 | |
Delmarva Power & Light Company [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 8 | 8 | 7 | ||
Related Party Transaction, Purchases from Related Party | 120 | 179 | 154 | ||
Operating and maintenance from affiliates | 162 | 32 | 19 | ||
Capitalized costs | 53 | 0 | 0 | ||
Equity in earnings (losses) of unconsolidated affiliates | 0 | 0 | 0 | ||
Cash dividends paid to parent | 96 | 112 | 54 | ||
Proceeds from Contributions from Parent | 150 | 0 | 152 | ||
Delmarva Power & Light Company [Member] | Corporate, Non-Segment [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating and maintenance | 0 | 174 | 202 | ||
Delmarva Power & Light Company [Member] | Exelon Generation Co LLC Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Related Party Transaction, Purchases from Related Party | [25] | 120 | 179 | 154 | |
Delmarva Power & Light Company [Member] | Commonwealth Edison Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 0 | 0 | ||
Delmarva Power & Light Company [Member] | Atlantic City Electric Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 0 | 0 | ||
Delmarva Power & Light Company [Member] | PHI Service Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 4 | 6 | 5 | ||
Operating and maintenance from affiliates | [26],[27] | 111 | 0 | 0 | |
Operating and maintenance | [26],[27] | 0 | 165 | 194 | |
Capitalized costs | [26] | 25 | 0 | 0 | |
Delmarva Power & Light Company [Member] | Exelon Corporation Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Cash dividends paid to parent | 96 | 112 | 54 | ||
Proceeds from Contributions from Parent | 150 | 0 | 152 | ||
Delmarva Power & Light Company [Member] | Exelon Business Services Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 0 | 0 | ||
Operating and maintenance from affiliates | [26] | 51 | 31 | 18 | |
Capitalized costs | [26] | 28 | 0 | 0 | |
Delmarva Power & Light Company [Member] | Pepco Energy Services Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating and maintenance | [28] | 0 | 9 | 8 | |
Delmarva Power & Light Company [Member] | Other Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 2 | 2 | ||
Operating and maintenance from affiliates | 0 | 1 | 1 | ||
Atlantic City Electric Company [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 3 | 2 | 3 | ||
Related Party Transaction, Purchases from Related Party | 29 | 29 | 37 | ||
Operating and maintenance from affiliates | 142 | 28 | 18 | ||
Capitalized costs | 41 | 0 | 0 | ||
Equity in earnings (losses) of unconsolidated affiliates | 0 | 0 | 0 | ||
Cash dividends paid to parent | 59 | 68 | 63 | ||
Proceeds from Contributions from Parent | 67 | 0 | 139 | ||
Atlantic City Electric Company [Member] | Exelon Generation Co LLC Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Related Party Transaction, Purchases from Related Party | [29] | 29 | 29 | 37 | |
Atlantic City Electric Company [Member] | PHI Service Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 2 | 1 | 2 | ||
Operating and maintenance from affiliates | [30],[31] | 98 | 0 | 0 | |
Operating and maintenance | [30],[31] | 0 | 135 | 155 | |
Capitalized costs | [30] | 21 | 0 | 0 | |
Atlantic City Electric Company [Member] | Exelon Corporation Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Cash dividends paid to parent | 59 | 68 | 63 | ||
Cash contributions received from affiliates | 67 | 0 | 139 | ||
Atlantic City Electric Company [Member] | Exelon Business Services Co Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating and maintenance from affiliates | [30] | 42 | 25 | 15 | |
Capitalized costs | [30] | 20 | 0 | 0 | |
Atlantic City Electric Company [Member] | Other Affiliate [Member] | |||||
Related Party Transaction [Line Items] | |||||
Operating revenues from affiliates | 1 | 1 | 1 | ||
Operating and maintenance from affiliates | $ 2 | $ 3 | $ 3 | ||
[1] | The intersegment profit associated with the sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory authoritative guidance. For Exelon, these amounts are included in operating revenues in the Consolidated Statements of Operations. See Note 4—Regulatory Matters for additional information. | ||||
[2] | Generation has an ICC-approved RFP contract with ComEd to provide a portion of ComEd’s electricity supply requirements. Generation also sells RECs and ZECs to ComEd. | ||||
[3] | Generation requires electricity for its own use at its generating stations. Generation purchases electricity and distribution and transmission services from PECO and BGE and only distribution and transmission services from ComEd for the delivery of electricity to its generating stations. | ||||
[4] | Generation provides electric supply to PECO under contracts executed through PECO’s competitive procurement process. In addition, Generation has a ten-year agreement with PECO to sell solar AECs. | ||||
[5] | Generation provides a portion of BGE’s energy requirements under its MDPSC-approved market-based SOS and gas commodity programs. | ||||
[6] | Generation provides electric supply to Pepco under contracts executed through Pepco's competitive procurement process approved by the MDPSC and DCPSC. | ||||
[7] | Generation provides a portion of DPL's energy requirements under its MDPSC and DPSC approved market based SOS and gas commodity programs. | ||||
[8] | Generation provides electric supply to ACE under contracts executed through ACE's competitive procurement process. | ||||
[9] | The balance consists of interest owed to Exelon Corporation related to the senior unsecured notes, as well as, expense related to certain invoices Exelon Corporation processed on behalf of Generation. | ||||
[10] | Generation receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||||
[11] | ComEd procures a portion of its electricity supply requirements from Generation under an ICC-approved RFP contract. ComEd also purchases RECs and ZECs from Generation. | ||||
[12] | ComEd receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||||
[13] | PECO provides energy to Generation for Generation’s own use. | ||||
[14] | PECO purchases electric supply from Generation under contracts executed through its competitive procurement process. In addition, PECO has five-year and ten-year agreements with Generation to purchase non-solar and solar AECs, respectively. | ||||
[15] | PECO receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||||
[16] | BGE provides energy to Generation for Generation’s own use. | ||||
[17] | BGE procures a portion of its electricity and gas supply requirements from Generation under its MDPSC-approved market-based SOS and gas commodity programs. | ||||
[18] | BGE receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||||
[19] | PHI receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||||
[20] | Pepco provides energy to Generation for Generation’s own use. | ||||
[21] | Pepco procures a portion of its electricity supply requirements from Generation under its MDPSC and DCPSC approved market based SOS commodity programs. | ||||
[22] | Due to the PHI entities' system conversion to Exelon's accounting systems on January 1, 2018, corporate support services received from PHISCO are reported in Operating and maintenance from affiliates in 2018. | ||||
[23] | Pepco receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||||
[24] | PES performed underground transmission, distribution construction and maintenance services, including services that are treated as capital costs, for Pepco. | ||||
[25] | DPL procures a portion of its electricity and gas supply requirements from Generation under its MDPSC and DPSC approved market based SOS and gas commodity programs. | ||||
[26] | DPL receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||||
[27] | Due to the PHI entities' system conversion to Exelon's accounting systems on January 1, 2018, corporate support services received from PHISCO are reported in Operating and maintenance from affiliates in 2018. | ||||
[28] | PES performed underground transmission construction services, including services that are treated as capital costs, for DPL. | ||||
[29] | ACE purchases electric supply from Generation under contracts executed through its competitive procurement process. | ||||
[30] | ACE receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||||
[31] | Due to the PHI entities' system conversion to Exelon's accounting systems on January 1, 2018, corporate support services received from PHISCO are reported in Operating and maintenance from affiliates in 2018. |
Related Party Transactions - _2
Related Party Transactions - Related Party Transactions included in Consolidated Balance Sheet (Details) - USD ($) | Dec. 31, 2018 | Dec. 31, 2017 | |
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | $ 5,000,000 | $ 5,000,000 | |
Long-term debt to financing trusts | 390,000,000 | 389,000,000 | |
ComEd Financing III Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 4,000,000 | 4,000,000 | |
Long-term debt to financing trusts | 206,000,000 | 205,000,000 | |
PECO Trust III Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 1,000,000 | 1,000,000 | |
Long-term debt to financing trusts | 81,000,000 | 81,000,000 | |
PECO Trust IV Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Long-term debt to financing trusts | 103,000,000 | 103,000,000 | |
Exelon Generation Co L L C [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 173,000,000 | 140,000,000 | |
Borrowings from Exelon intercompany money pool | 100,000,000 | 54,000,000 | |
Payables to affiliates, current | 139,000,000 | 123,000,000 | |
Long-term debt due to affiliates | 898,000,000 | 910,000,000 | |
Payables to affiliates, noncurrent | 2,606,000,000 | 3,065,000,000 | |
Exelon Generation Co L L C [Member] | PECO Energy Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | [1] | 30,000,000 | 26,000,000 |
Payables to affiliates, current | [1] | 0 | 4,000,000 |
Payables to affiliates, noncurrent | [2] | 389,000,000 | 537,000,000 |
Exelon Generation Co L L C [Member] | Commonwealth Edison Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | [3] | 69,000,000 | 28,000,000 |
Payables to affiliates, current | 19,000,000 | 12,000,000 | |
Due to Related Parties, Current | [3] | 14,000,000 | 0 |
Payables to affiliates, noncurrent | [2] | 2,217,000,000 | 2,528,000,000 |
Exelon Generation Co L L C [Member] | Delmarva Power & Light Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | [4] | 7,000,000 | 12,000,000 |
Exelon Generation Co L L C [Member] | Potomac Electric Power Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | [5] | 28,000,000 | 36,000,000 |
Exelon Generation Co L L C [Member] | Atlantic City Electric Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | [6] | 5,000,000 | 6,000,000 |
Exelon Generation Co L L C [Member] | Baltimore Gas And Electric Company Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | [7] | 24,000,000 | 24,000,000 |
Exelon Generation Co L L C [Member] | PHI Service Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | [8] | 0 | 1,000,000 |
Exelon Generation Co L L C [Member] | Potomac Capital Investment Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Borrowings from Exelon intercompany money pool | 0 | 54,000,000 | |
Exelon Generation Co L L C [Member] | Other Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 10,000,000 | 7,000,000 | |
Payables to affiliates, current | 8,000,000 | 12,000,000 | |
Exelon Generation Co L L C [Member] | Exelon Corporation Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Borrowings from Exelon intercompany money pool | 100,000,000 | 0 | |
Payables to affiliates, current | [9] | 17,000,000 | 21,000,000 |
Long-term debt due to affiliates | [10] | 898,000,000 | 910,000,000 |
Exelon Generation Co L L C [Member] | Exelon Business Services Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [8] | 95,000,000 | 74,000,000 |
Commonwealth Edison Co [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 20,000,000 | 13,000,000 | |
Receivable from affiliates, noncurrent | 2,217,000,000 | 2,528,000,000 | |
Payables to affiliates, current | 119,000,000 | 74,000,000 | |
Long-term debt to financing trusts | 205,000,000 | 205,000,000 | |
Commonwealth Edison Co [Member] | Exelon Generation Co LLC Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 19,000,000 | 12,000,000 | |
Receivable from affiliates, noncurrent | [11] | 2,217,000,000 | 2,528,000,000 |
Payables to affiliates, current | [12] | 55,000,000 | 28,000,000 |
Commonwealth Edison Co [Member] | ComEd Financing III Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 4,000,000 | 4,000,000 | |
Long-term debt to financing trusts | 205,000,000 | 205,000,000 | |
Commonwealth Edison Co [Member] | Voluntary Employee Beneficiary Association Trust Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Prepaid voluntary employee beneficiary association trust | [13] | 5,000,000 | 2,000,000 |
Receivables from affiliates, current | 1,000,000 | 1,000,000 | |
Commonwealth Edison Co [Member] | Exelon Corporation Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 4,000,000 | 3,000,000 | |
Commonwealth Edison Co [Member] | Exelon Business Services Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [14] | 56,000,000 | 39,000,000 |
PECO Energy Co [Member] | |||
Related Party Transaction [Line Items] | |||
Receivable from affiliates, noncurrent | 389,000,000 | 537,000,000 | |
Payables to affiliates, current | 59,000,000 | 53,000,000 | |
Long-term debt to financing trusts | [15] | 184,000,000 | 184,000,000 |
PECO Energy Co [Member] | Exelon Generation Co LLC Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivable from affiliates, noncurrent | [16] | 389,000,000 | 537,000,000 |
Payables to affiliates, current | [17] | 30,000,000 | 22,000,000 |
PECO Energy Co [Member] | PECO Trust III Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 1,000,000 | 1,000,000 | |
Long-term debt to financing trusts | 81,000,000 | 81,000,000 | |
PECO Energy Co [Member] | PECO Trust IV Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Long-term debt to financing trusts | 103,000,000 | 103,000,000 | |
PECO Energy Co [Member] | Voluntary Employee Beneficiary Association Trust Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Prepaid voluntary employee beneficiary association trust | [18] | 1,000,000 | 0 |
PECO Energy Co [Member] | Exelon Corporation Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 2,000,000 | 1,000,000 | |
PECO Energy Co [Member] | Exelon Business Services Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [19] | 26,000,000 | 29,000,000 |
Baltimore Gas and Electric Company [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 1,000,000 | 1,000,000 | |
Payables to affiliates, current | 65,000,000 | 52,000,000 | |
Baltimore Gas and Electric Company [Member] | Exelon Generation Co LLC Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [20] | 24,000,000 | 24,000,000 |
Baltimore Gas and Electric Company [Member] | Other Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 1,000,000 | 1,000,000 | |
Payables to affiliates, current | 1,000,000 | 2,000,000 | |
Baltimore Gas and Electric Company [Member] | Exelon Corporation Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 2,000,000 | 1,000,000 | |
Baltimore Gas and Electric Company [Member] | Exelon Business Services Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [21] | 38,000,000 | 25,000,000 |
Pepco Holdings LLC [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 94,000,000 | 90,000,000 | |
Pepco Holdings LLC [Member] | Exelon Generation Co LLC Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 40,000,000 | 54,000,000 | |
Pepco Holdings LLC [Member] | Baltimore Gas And Electric Company Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 0 | 1,000,000 | |
Pepco Holdings LLC [Member] | Other Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 7,000,000 | 5,000,000 | |
Pepco Holdings LLC [Member] | Exelon Corporation Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 6,000,000 | 6,000,000 | |
Pepco Holdings LLC [Member] | Exelon Business Services Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [22] | 41,000,000 | 24,000,000 |
Potomac Electric Power Company [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 1,000,000 | 0 | |
Payables to affiliates, current | 62,000,000 | 74,000,000 | |
Potomac Electric Power Company [Member] | Exelon Generation Co LLC Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [23] | 28,000,000 | 36,000,000 |
Potomac Electric Power Company [Member] | Delmarva Power & Light Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 1,000,000 | 0 | |
Potomac Electric Power Company [Member] | PHI Service Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [24] | 14,000,000 | 27,000,000 |
Potomac Electric Power Company [Member] | Exelon Corporation Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 1,000,000 | 0 | |
Potomac Electric Power Company [Member] | Exelon Business Services Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [24] | 19,000,000 | 11,000,000 |
Delmarva Power & Light Company [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 33,000,000 | 46,000,000 | |
Delmarva Power & Light Company [Member] | Exelon Generation Co LLC Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [25] | 7,000,000 | 12,000,000 |
Delmarva Power & Light Company [Member] | Potomac Electric Power Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 1,000,000 | 0 | |
Delmarva Power & Light Company [Member] | Atlantic City Electric Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 1,000,000 | 0 | |
Delmarva Power & Light Company [Member] | PHI Service Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [26] | 12,000,000 | 27,000,000 |
Delmarva Power & Light Company [Member] | Exelon Corporation Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 1,000,000 | 0 | |
Delmarva Power & Light Company [Member] | Exelon Business Services Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [26] | 11,000,000 | 7,000,000 |
Atlantic City Electric Company [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 1,000,000 | 0 | |
Payables to affiliates, current | 28,000,000 | 29,000,000 | |
Atlantic City Electric Company [Member] | Delmarva Power & Light Company [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 1,000,000 | 0 | |
Atlantic City Electric Company [Member] | Exelon Generation Co LLC Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [27] | 5,000,000 | 6,000,000 |
Atlantic City Electric Company [Member] | PHI Service Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [28] | 13,000,000 | 18,000,000 |
Atlantic City Electric Company [Member] | Other Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | 2,000,000 | 0 | |
Atlantic City Electric Company [Member] | Exelon Business Services Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Payables to affiliates, current | [28] | 8,000,000 | 5,000,000 |
Parent Company [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 44,000,000 | 33,000,000 | |
Note receivable from affiliates, current | 216,000,000 | 217,000,000 | |
Payables to affiliates, current | 360,000,000 | 360,000,000 | |
Parent Company [Member] | Exelon Generation Co L L C [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 17,000,000 | 21,000,000 | |
Note receivable from affiliates, current | [29] | 100,000,000 | 0 |
Parent Company [Member] | PHI Service Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | 6,000,000 | 6,000,000 | |
Parent Company [Member] | Exelon Business Services Co Affiliate [Member] | |||
Related Party Transaction [Line Items] | |||
Receivables from affiliates, current | [30] | 13,000,000 | 1,000,000 |
Note receivable from affiliates, current | [30] | $ 116,000,000 | $ 217,000,000 |
[1] | Generation provides electric supply to PECO under contracts executed through PECO’s competitive procurement process. In addition, Generation has a ten-year agreement with PECO to sell solar AECs. | ||
[2] | Generation has long-term payables to ComEd and PECO as a result of the nuclear decommissioning contractual construct whereby, to the extent NDT funds are greater than the underlying ARO at the end of decommissioning, such amounts are due back to ComEd and PECO, as applicable, for payment to their respective customers. See Note 15—Asset Retirement Obligations for additional information. | ||
[3] | Generation has an ICC-approved RFP contract with ComEd to provide a portion of ComEd’s electricity supply requirements. Generation also sells RECs and ZECs to ComEd. | ||
[4] | Generation provides a portion of DPL's energy requirements under its MDPSC and DPSC approved market based SOS and gas commodity programs. | ||
[5] | Generation provides electric supply to Pepco under contracts executed through Pepco's competitive procurement process approved by the MDPSC and DCPSC. | ||
[6] | Generation provides electric supply to ACE under contracts executed through ACE's competitive procurement process. | ||
[7] | Generation provides a portion of BGE’s energy requirements under its MDPSC-approved market-based SOS and gas commodity programs. | ||
[8] | Generation receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||
[9] | The balance consists of interest owed to Exelon Corporation related to the senior unsecured notes, as well as, expense related to certain invoices Exelon Corporation processed on behalf of Generation. | ||
[10] | In connection with the debt obligations assumed by Exelon as part of the Constellation merger, Exelon and subsidiaries of Generation (former Constellation subsidiaries) assumed intercompany loan agreements that mirror the terms and amounts of the third-party debt obligations of Exelon, resulting in intercompany notes payable included in Long-term Debt to affiliates in Generation’s Consolidated Balance Sheets and intercompany notes receivable at Exelon Corporate, which are eliminated in consolidation in Exelon’s Consolidated Balance Sheets. | ||
[11] | ComEd has a long-term receivable from Generation as a result of the nuclear decommissioning contractual construct for generating facilities previously owned by ComEd. To the extent the assets associated with decommissioning are greater than the applicable ARO at the end of decommissioning, such amounts are due back to ComEd for payment to ComEd’s customers. | ||
[12] | ComEd procures a portion of its electricity supply requirements from Generation under an ICC-approved RFP contract. ComEd also purchases RECs and ZECs from Generation. | ||
[13] | The voluntary employee benefit association trusts covering active employees are included in corporate operations and are funded by the Registrants. A prepayment to the active welfare plans has accumulated due to actuarially determined contribution rates, which are the basis for ComEd’s contributions to the plans, being higher than actual claim expense incurred by the plans over time. The prepayment is included in other current assets. | ||
[14] | ComEd receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||
[15] | Amounts owed to this financing trust are recorded as Long-term debt to financing trusts within PECO’s Consolidated Balance Sheets. | ||
[16] | PECO has a long-term receivable from Generation as a result of the nuclear decommissioning contractual construct, whereby, to the extent the assets associated with decommissioning are greater than the applicable ARO at the end of decommissioning, such amounts are due back to PECO for payment to PECO’s customers. | ||
[17] | PECO purchases electric supply from Generation under contracts executed through its competitive procurement process. In addition, PECO has five-year and ten-year agreements with Generation to purchase non-solar and solar AECs, respectively. | ||
[18] | The voluntary employee beneficiary association trusts covering active employees are included in corporate operations and are funded by the Registrants. A prepayment to the active welfare plans has accumulated due to actuarially determined contribution rates, which are the basis for PECO’s contributions to the plans, being higher than actual claim expense incurred by the plans over time. | ||
[19] | PECO receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||
[20] | BGE procures a portion of its electricity and gas supply requirements from Generation under its MDPSC-approved market-based SOS and gas commodity programs. | ||
[21] | BGE receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||
[22] | PHI receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||
[23] | Pepco procures a portion of its electricity supply requirements from Generation under its MDPSC and DCPSC approved market based SOS commodity programs. | ||
[24] | Pepco receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||
[25] | DPL procures a portion of its electricity and gas supply requirements from Generation under its MDPSC and DPSC approved market based SOS and gas commodity programs. | ||
[26] | DPL receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||
[27] | ACE purchases electric supply from Generation under contracts executed through its competitive procurement process. | ||
[28] | ACE receives a variety of corporate support services from BSC and PHISCO, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. A portion of such services is capitalized. | ||
[29] | In connection with the debt obligations assumed by Exelon as part of the Constellation merger, Exelon and subsidiaries of Generation (former Constellation subsidiaries) assumed intercompany loan agreements that mirror the terms and amounts of the third-party debt obligations of Exelon, resulting in intercompany notes payable included in Long-Term Debt to affiliates in Generation’s Consolidated Balance Sheets and intercompany notes receivable at Exelon Corporate, which are eliminated in consolidation in Exelon’s Consolidated Balance Sheets. | ||
[30] | Exelon Corporate receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. |
Quarterly Data (Unaudited) - Qu
Quarterly Data (Unaudited) - Quarterly Operating Results (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |||||||||
Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2017 | Jun. 30, 2017 | Mar. 31, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating Revenues | $ 8,814 | $ 9,403 | $ 8,076 | $ 9,693 | $ 8,384 | $ 8,768 | $ 7,665 | $ 8,747 | $ 35,985 | $ 33,565 | $ 31,366 |
Operating income (loss) | 708 | 1,146 | 942 | 1,101 | 1,288 | 1,499 | 300 | 1,308 | 3,898 | 4,395 | 3,212 |
Net income attributable to common shareholders | 152 | 733 | 539 | 585 | 1,880 | 823 | 95 | 990 | 2,010 | 3,786 | 1,121 |
Net income (loss) | 2,084 | 3,876 | 1,196 | ||||||||
Exelon Generation Co L L C [Member] | |||||||||||
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating Revenues | 5,069 | 5,278 | 4,579 | 5,512 | 4,657 | 4,750 | 4,216 | 4,878 | 20,437 | 18,500 | 17,757 |
Operating income (loss) | 35 | 311 | 282 | 347 | 504 | 497 | (427) | 373 | 975 | 947 | 820 |
Net income (loss) attributable to membership interest | (178) | 234 | 178 | 136 | 2,224 | 304 | (235) | 418 | 370 | 2,710 | 483 |
Net income (loss) | 443 | 2,798 | 550 | ||||||||
Commonwealth Edison Co [Member] | |||||||||||
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating Revenues | 1,373 | 1,598 | 1,398 | 1,512 | 1,309 | 1,571 | 1,357 | 1,298 | 5,882 | 5,536 | 5,254 |
Operating income (loss) | 242 | 323 | 288 | 292 | 286 | 404 | 319 | 314 | 1,146 | 1,323 | 1,205 |
Net income (loss) | 141 | 193 | 164 | 165 | 120 | 189 | 118 | 141 | 664 | 567 | 378 |
PECO Energy Co [Member] | |||||||||||
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating Revenues | 765 | 757 | 653 | 866 | 729 | 715 | 630 | 796 | 3,038 | 2,870 | 2,994 |
Operating income (loss) | 165 | 154 | 127 | 142 | 157 | 169 | 137 | 192 | 587 | 655 | 702 |
Net income (loss) | 124 | 126 | 96 | 113 | 107 | 112 | 88 | 127 | 460 | 434 | 438 |
Baltimore Gas and Electric Company [Member] | |||||||||||
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating Revenues | 799 | 731 | 662 | 977 | 813 | 738 | 674 | 951 | 3,169 | 3,176 | 3,233 |
Operating income (loss) | 109 | 103 | 85 | 177 | 163 | 124 | 98 | 228 | 474 | 614 | 550 |
Net income attributable to common shareholders | 313 | 307 | 286 | ||||||||
Net income (loss) | 71 | 63 | 51 | 128 | 76 | 62 | 45 | 125 | 313 | 307 | 294 |
Pepco Holdings LLC [Member] | |||||||||||
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating Revenues | 1,117 | 1,361 | 1,076 | 1,251 | 1,121 | 1,310 | 1,074 | 1,175 | 4,805 | 4,679 | |
Operating income (loss) | 126 | 245 | 153 | 126 | 159 | 285 | 148 | 180 | 650 | 769 | |
Net income (loss) attributable to membership interest | 62 | 187 | 84 | 65 | 4 | 153 | 66 | 140 | 398 | 362 | |
Net income (loss) | 398 | 362 | |||||||||
Potomac Electric Power Company [Member] | |||||||||||
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating Revenues | 531 | 628 | 523 | 557 | 510 | 604 | 514 | 530 | 2,239 | 2,158 | 2,186 |
Operating income (loss) | 65 | 112 | 85 | 56 | 87 | 149 | 84 | 79 | 320 | 399 | 174 |
Net income (loss) | 36 | 89 | 54 | 31 | 17 | 87 | 43 | 58 | 210 | 205 | 42 |
Delmarva Power & Light Company [Member] | |||||||||||
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating Revenues | 331 | 328 | 289 | 384 | 330 | 327 | 282 | 362 | 1,332 | 1,300 | 1,277 |
Operating income (loss) | 48 | 51 | 42 | 49 | 52 | 59 | 41 | 78 | 190 | 229 | 50 |
Net income (loss) | 30 | 33 | 26 | 31 | 14 | 31 | 19 | 57 | 120 | 121 | (9) |
Atlantic City Electric Company [Member] | |||||||||||
Selected Quarterly Financial Information [Line Items] | |||||||||||
Operating Revenues | 254 | 406 | 265 | 310 | 271 | 370 | 270 | 275 | 1,236 | 1,186 | 1,257 |
Operating income (loss) | 14 | 84 | 25 | 23 | 28 | 79 | 25 | 25 | 149 | 157 | 7 |
Net income (loss) | $ (1) | $ 61 | $ 8 | $ 7 | $ 0 | $ 41 | $ 8 | $ 28 | $ 75 | $ 77 | $ (42) |
Quarterly Data (Unaudited) - _2
Quarterly Data (Unaudited) - Quarterly Per Share Information (Details) - $ / shares | 3 Months Ended | 12 Months Ended | |||||||||
Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2017 | Jun. 30, 2017 | Mar. 31, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Quarterly Financial Data [Abstract] | |||||||||||
Net Income per Basic Share | $ 0.16 | $ 0.76 | $ 0.56 | $ 0.61 | $ 1.95 | $ 0.86 | $ 0.10 | $ 1.07 | $ 2.08 | $ 4 | $ 1.21 |
Net Income per Diluted Share | $ 0.16 | $ 0.76 | $ 0.56 | $ 0.60 | $ 1.94 | $ 0.85 | $ 0.10 | $ 1.06 | $ 2.07 | $ 3.99 | $ 1.21 |
Subsequent Events Subsequent _2
Subsequent Events Subsequent Events - Narrative (Details) - Exelon Generation Co L L C [Member] - Subsequent Event [Member] $ in Millions | Dec. 31, 2018USD ($) |
Subsequent Event [Line Items] | |
Net long-lived assets | $ 750 |
Non-recourse debt | 510 |
Antelope Valley [Member] | |
Subsequent Event [Line Items] | |
Net long-lived assets | 1,990 |
Antelope Valley [Member] | ExGenRenewablesIVNov2024 [Member] | |
Subsequent Event [Line Items] | |
Non-recourse debt | $ 830 |
Schedule I - Condensed Financ_2
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) - Condensed Statements of Operations and Other Comprehensive Income (Details) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | ||||||||||
Dec. 31, 2018 | Sep. 30, 2018 | Jun. 30, 2018 | Mar. 31, 2018 | Dec. 31, 2017 | Sep. 30, 2017 | Jun. 30, 2017 | Mar. 31, 2017 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Operating Expenses [Abstract] | ||||||||||||
Total operating expenses | $ 32,143 | $ 29,619 | $ 28,106 | |||||||||
Operating income (loss) | $ 708 | $ 1,146 | $ 942 | $ 1,101 | $ 1,288 | $ 1,499 | $ 300 | $ 1,308 | 3,898 | 4,395 | 3,212 | |
Other income and (deductions) | ||||||||||||
Interest expense, net | (1,529) | (1,524) | (1,495) | |||||||||
Equity in earnings (losses) of unconsolidated affiliates | (28) | (32) | (24) | |||||||||
Other, net | (112) | 947 | 297 | |||||||||
Total other income and (deductions) | (1,666) | (613) | (1,239) | |||||||||
Income taxes | $ 26 | 120 | (126) | 753 | ||||||||
Net income (loss) | 2,084 | 3,876 | 1,196 | |||||||||
Pension and non-pension postretirement benefit plans: | ||||||||||||
Prior service benefit reclassified to periodic benefit cost | (66) | (56) | (48) | |||||||||
Actuarial loss reclassified to periodic cost, net of tax | 247 | 197 | 184 | |||||||||
Unrealized gain on cash flow hedges | 12 | 3 | 2 | |||||||||
Unrealized gain on marketable securities | 0 | 6 | 1 | |||||||||
Unrealized (loss) gain on foreign currency translation | (10) | 7 | 10 | |||||||||
Other comprehensive income (loss) | 42 | 171 | (36) | |||||||||
Comprehensive Income | 2,051 | 3,959 | 1,085 | |||||||||
Exelon Corporate [Member] | ||||||||||||
Operating Expenses [Abstract] | ||||||||||||
Operating and maintenance | (5) | 10 | 221 | |||||||||
Operating and maintenance from affiliates | [1] | 9 | 25 | 51 | ||||||||
Other | 4 | 4 | 4 | |||||||||
Total operating expenses | 8 | 39 | 276 | |||||||||
Operating income (loss) | (8) | (39) | (276) | |||||||||
Other income and (deductions) | ||||||||||||
Interest expense, net | (312) | (315) | (312) | |||||||||
Equity in earnings (losses) of unconsolidated affiliates | 2,188 | 4,414 | 1,508 | |||||||||
Interest income from affiliates, net | 42 | 40 | 39 | |||||||||
Other, net | 3 | 1 | 7 | |||||||||
Total other income and (deductions) | 1,921 | 4,140 | 1,242 | |||||||||
Income before income taxes | 1,913 | 4,101 | 966 | |||||||||
Income taxes | (97) | 315 | (155) | |||||||||
Net income (loss) | 2,010 | 3,786 | 1,121 | |||||||||
Pension and non-pension postretirement benefit plans: | ||||||||||||
Prior service benefit reclassified to periodic benefit cost | (66) | (56) | (48) | |||||||||
Actuarial loss reclassified to periodic cost, net of tax | 247 | 197 | 184 | |||||||||
Other Comprehensive Income (Loss), Defined Benefit Plan, Settlement and Curtailment Gain (Loss), after Tax | (143) | 10 | (181) | |||||||||
Unrealized gain on cash flow hedges | 12 | 3 | 2 | |||||||||
Unrealized gain (loss) on equity investments | 1 | 6 | (4) | |||||||||
Unrealized gain on marketable securities | 0 | 6 | 1 | |||||||||
Unrealized (loss) gain on foreign currency translation | (10) | 7 | 10 | |||||||||
Other comprehensive income (loss) | 41 | 173 | (36) | |||||||||
Comprehensive Income | $ 2,051 | $ 3,959 | $ 1,085 | |||||||||
[1] | Exelon Corporate receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. |
Schedule I - Condensed Financ_3
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) - Condensed Statements of Cash Flows (Details) - USD ($) $ in Millions | 12 Months Ended | ||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | |
Net cash flows provided by (used in) operating activities | $ 8,644 | $ 7,480 | $ 8,461 |
Cash flows from investing activities | |||
Other investing activities | 58 | (43) | (153) |
Net cash flows provided by (used in) investing activities | (7,834) | (7,971) | (15,450) |
Cash flows from financing activities | |||
Issuance of long-term debt | 3,115 | 3,470 | 4,716 |
Proceeds from short-term borrowings with maturities greater than 90 days | 126 | 621 | 240 |
Retirement of long-term debt | (1,786) | (2,490) | (1,936) |
Common stock issued from treasury stock | 0 | 1,150 | 0 |
Dividends paid on common stock | (1,332) | (1,236) | (1,166) |
Proceeds from employee stock plans | 105 | 150 | 55 |
Other financing activities | (108) | (83) | (85) |
Net cash flows provided by (used in) financing activities | (219) | 767 | 1,191 |
Increase (Decrease) in cash, cash equivalents and restricted cash | 591 | 276 | (5,798) |
Cash, cash equivalents and restricted cash at beginning of period | 898 | 635 | 6,502 |
Cash, cash equivalents and restricted cash at end of period | 1,349 | 898 | 635 |
Exelon Corporate [Member] | |||
Net cash flows provided by (used in) operating activities | 2,581 | 1,921 | 1,029 |
Cash flows from investing activities | |||
Changes in Exelon intercompany money pool | 1 | (129) | 1,390 |
Investment in affiliates | (1,236) | (1,717) | (1,757) |
Acquisition of business | 0 | 0 | 6,962 |
Other investing activities | 0 | (5) | 5 |
Net cash flows provided by (used in) investing activities | (1,235) | (1,851) | (7,324) |
Cash flows from financing activities | |||
Issuance of long-term debt | 0 | 0 | 1,800 |
Proceeds from short-term borrowings with maturities greater than 90 days | 0 | 500 | 0 |
Retirement of long-term debt | 0 | (569) | (46) |
Common stock issued from treasury stock | 0 | 1,150 | 0 |
Dividends paid on common stock | (1,332) | (1,236) | (1,166) |
Proceeds from employee stock plans | 105 | 150 | 55 |
Other financing activities | (4) | (9) | (20) |
Net cash flows provided by (used in) financing activities | (1,231) | (14) | 623 |
Increase (Decrease) in cash, cash equivalents and restricted cash | 115 | 56 | (5,672) |
Cash, cash equivalents and restricted cash at beginning of period | 74 | 18 | 5,690 |
Cash, cash equivalents and restricted cash at end of period | $ 189 | $ 74 | $ 18 |
Schedule I - Condensed Financ_4
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) - Condensed Balance Sheet (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | Dec. 31, 2015 | Feb. 17, 2012 | |
Current assets | ||||||
Cash and cash equivalents | $ 1,349 | $ 898 | $ 635 | $ 6,502 | ||
Accounts receivable, net | ||||||
Other accounts receivable | 1,256 | 1,132 | ||||
Regulatory assets, current | 1,222 | 1,267 | ||||
Other | 1,238 | 1,260 | ||||
Total current assets | 13,360 | 11,896 | ||||
Property, plant and equipment, net | 76,707 | 74,202 | ||||
Deferred debits and other assets | ||||||
Regulatory assets, noncurrent | 8,237 | 8,021 | ||||
Other | 1,575 | 1,330 | ||||
Total assets | [1] | 119,666 | 116,770 | |||
Current liabilities | ||||||
Short-term borrowings | 714 | 929 | ||||
Long-term debt due within one year | 1,349 | 2,088 | ||||
Accounts payable | 3,800 | 3,532 | ||||
Accrued expenses | 2,112 | 1,837 | ||||
Payables to affiliates, current | 5 | 5 | ||||
Regulatory Liability, Current | 644 | 523 | ||||
Other | 1,035 | 1,069 | ||||
Total current liabilities | 11,404 | 10,798 | ||||
Long-term debt | 34,075 | 32,176 | ||||
Deferred credits and other liabilities | ||||||
Regulatory liabilities, noncurrent | 9,559 | 9,865 | ||||
Pension obligations | 3,988 | 3,736 | ||||
Non-pension postretirement benefit obligations | 1,928 | 2,093 | ||||
Other | 2,130 | 2,097 | ||||
Total deferred credits and other liabilities | 40,727 | 41,220 | ||||
Total liabilities | [1] | 86,596 | 84,583 | |||
Commitments and Contingencies | $ 1,000 | |||||
Shareholders’ equity | ||||||
Common stock | 19,116 | 18,964 | ||||
Treasury stock, at cost | (123) | (123) | ||||
Retained earnings | 14,766 | 14,081 | ||||
Accumulated other comprehensive income (loss), net | (2,995) | (3,026) | ||||
Total shareholders’ equity | 30,764 | 29,896 | ||||
Total liabilities and equity | 119,666 | 116,770 | ||||
Exelon Corporate [Member] | ||||||
Current assets | ||||||
Cash and cash equivalents | 189 | 74 | $ 18 | $ 5,690 | ||
Accounts receivable, net | ||||||
Other accounts receivable | 48 | 431 | ||||
Accounts receivable from affiliates, current | 44 | 33 | ||||
Note receivable from affiliates, current | 216 | 217 | ||||
Regulatory assets, current | 182 | 284 | ||||
Other | 4 | 4 | ||||
Total current assets | 683 | 1,043 | ||||
Property, plant and equipment, net | 48 | 50 | ||||
Deferred debits and other assets | ||||||
Regulatory assets, noncurrent | 3,742 | 3,697 | ||||
Investments in affiliates | 40,448 | 39,311 | ||||
Deferred income taxes | 1,455 | 1,431 | ||||
Notes receivable from affiliates, noncurrent | 898 | 910 | ||||
Other | 235 | 234 | ||||
Total deferred debits and other assets | 46,778 | 45,583 | ||||
Total assets | 47,509 | 46,676 | ||||
Current liabilities | ||||||
Short-term borrowings | 500 | 500 | ||||
Accounts payable | 1 | 2 | ||||
Accrued expenses | 184 | 99 | ||||
Payables to affiliates, current | 360 | 360 | ||||
Regulatory Liability, Current | 15 | 16 | ||||
Pension obligations | 63 | 65 | ||||
Other | 14 | 46 | ||||
Total current liabilities | 1,137 | 1,088 | ||||
Long-term debt | 7,147 | 7,161 | ||||
Deferred credits and other liabilities | ||||||
Regulatory liabilities, noncurrent | 32 | 15 | ||||
Pension obligations | 7,795 | 7,792 | ||||
Non-pension postretirement benefit obligations | 199 | 322 | ||||
Deferred income taxes | 233 | 220 | ||||
Other | 202 | 180 | ||||
Total deferred credits and other liabilities | 8,461 | 8,529 | ||||
Total liabilities | 16,745 | 16,778 | ||||
Commitments and Contingencies | ||||||
Shareholders’ equity | ||||||
Common stock | 19,116 | 18,966 | ||||
Treasury stock, at cost | (123) | (123) | ||||
Retained earnings | 14,766 | 14,081 | ||||
Accumulated other comprehensive income (loss), net | (2,995) | (3,026) | ||||
Total shareholders’ equity | 30,764 | 29,898 | ||||
Total liabilities and equity | $ 47,509 | $ 46,676 | ||||
[1] | Exelon’s consolidated assets include $9,667 million and $9,597 million at December 31, 2018 and 2017, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,548 million and $3,618 million at December 31, 2018 and 2017, respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 2–Variable Interest Entities for additional information. |
Schedule I - Condensed Financ_5
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) - Condensed Balance Sheet - Parenthetical (Details) - $ / shares | Dec. 31, 2018 | Dec. 31, 2017 |
Common stock, par value | $ 0 | $ 0 |
Common stock, shares authorized | 2,000,000,000 | 2,000,000,000 |
Common stock, shares outstanding | 968,187,955 | 963,335,888 |
Treasury stock, shares held | 2,000,000 | 2,000,000 |
Exelon Corporate [Member] | ||
Common stock, par value | $ 0 | $ 0 |
Common stock, shares authorized | 2,000,000,000 | 2,000,000,000 |
Treasury stock, shares held | 35,000,000 | 35,000,000 |
Schedule I - Condensed Financ_6
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) - Basis of Presentation - Narrative (Details) - Exelon Corporate [Member] | Dec. 31, 2018 |
Schedule of Equity Method Investments [Line Items] | |
Ownership interest | 100.00% |
Commonwealth Edison Co [Member] | |
Schedule of Equity Method Investments [Line Items] | |
Ownership interest | 99.00% |
Baltimore Gas and Electric Company [Member] | |
Schedule of Equity Method Investments [Line Items] | |
Ownership interest | 100.00% |
Baltimore Gas and Electric Company [Member] | Preferred Stock [Member] | |
Schedule of Equity Method Investments [Line Items] | |
Ownership interest | 0.00% |
Schedule I - Condensed Financ_7
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) - Debt and Credit Agreements - Narrative (Details) $ in Millions | 12 Months Ended | |
Dec. 31, 2018USD ($) | ||
Line of Credit Facility [Line Items] | ||
Maximum Program Size | $ 9,704 | [1] |
Line of Credit Facility, Capacity Available for Trade Purchases | 7,687 | |
Revolving Credit Facility [Member] | Exelon Corporate [Member] | ||
Line of Credit Facility [Line Items] | ||
Maximum Program Size | 600 | [1] |
Line of Credit Facility, Capacity Available for Trade Purchases | 591 | |
Corporate, Non-Segment [Member] | Exelon Corporate [Member] | ||
Line of Credit Facility [Line Items] | ||
Short-term Bank Loans and Notes Payable | $ 500 | |
Debt Instrument, Interest Rate Terms | LIBOR plus 1% | |
[1] | Excludes $135 million of credit facility agreements arranged at minority and community banks at Generation, ComEd, PECO, BGE, Pepco, DPL and ACE with aggregate commitments of $49 million, $33 million, $34 million, $5 million, $5 million, $5 million and $5 million, respectively. These facilities expire on October 11, 2019. These facilities are solely utilized to issue letters of credit. As of December 31, 2018, letters of credit issued under these facilities totaled $5 million and $2 million for Generation and BGE, respectively. |
Schedule I - Condensed Financ_8
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) - Debt and Credit Agreements - Schedule of Outstanding Long-term Debt (Details) - USD ($) $ in Millions | Dec. 31, 2018 | Dec. 31, 2017 | Jun. 30, 2014 | |
Debt Instrument [Line Items] | ||||
Long-term Debt, Gross | $ 34,911 | $ 33,657 | ||
Unamortized debt discount and premium, net | (66) | (57) | ||
Unamortized debt issuance costs | 216 | 201 | ||
Long-term debt | 34,075 | 32,176 | ||
Junior Subordinated Debt [Member] | ||||
Debt Instrument [Line Items] | ||||
Long-term Debt, Gross | 1,150 | $ 1,150 | ||
Debt Instrument, Interest Rate, Stated Percentage | 3.497% | 2.50% | ||
Senior Notes [Member] | ||||
Debt Instrument [Line Items] | ||||
Long-term Debt, Gross | $ 11,285 | $ 11,285 | ||
Maximum [Member] | Junior Subordinated Debt [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt Instrument, Interest Rate, Stated Percentage | 3.50% | |||
Maximum [Member] | Senior Notes [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt Instrument, Interest Rate, Stated Percentage | 7.60% | |||
Minimum [Member] | Senior Notes [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt Instrument, Interest Rate, Stated Percentage | 2.45% | |||
Exelon Corporate [Member] | ||||
Debt Instrument [Line Items] | ||||
Long-term Debt, Gross | $ 7,039 | 7,039 | ||
Unamortized debt discount and premium, net | (7) | (8) | ||
Unamortized debt issuance costs | (47) | (49) | ||
Fair value adjustment of consolidated subsidiary | 162 | 179 | ||
Long-term debt | 7,147 | 7,161 | ||
Exelon Corporate [Member] | Junior Subordinated Debt [Member] | ||||
Debt Instrument [Line Items] | ||||
Long-term Debt, Gross | 1,150 | 1,150 | ||
Exelon Corporate [Member] | Senior Notes [Member] | ||||
Debt Instrument [Line Items] | ||||
Long-term Debt, Gross | [1] | $ 5,889 | $ 5,889 | |
Exelon Corporate [Member] | Maximum [Member] | Junior Subordinated Debt [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt Instrument, Interest Rate, Stated Percentage | 3.50% | |||
Exelon Corporate [Member] | Maximum [Member] | Senior Notes [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt Instrument, Interest Rate, Stated Percentage | [1] | 7.60% | ||
Exelon Corporate [Member] | Minimum [Member] | Senior Notes [Member] | ||||
Debt Instrument [Line Items] | ||||
Debt Instrument, Interest Rate, Stated Percentage | [1] | 2.45% | ||
[1] | Senior unsecured notes include mirror debt that is held on both Generation and Exelon Corporation's balance sheets. |
Schedule I - Condensed Financ_9
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) - Debt and Credit Agreements - Schedule of Debt Maturities (Details) $ in Millions | Dec. 31, 2018USD ($) | |
Debt Instrument [Line Items] | ||
2,019 | $ 1,349 | |
2,020 | 3,528 | |
2,021 | 1,511 | |
2,022 | 3,084 | |
2,023 | 850 | |
Thereafter | 24,979 | [1] |
Total | 35,301 | |
Exelon Corporate [Member] | ||
Debt Instrument [Line Items] | ||
2,019 | 0 | |
2,020 | 1,450 | |
2,021 | 300 | |
2,022 | 1,150 | |
2,023 | 0 | |
Thereafter | 4,139 | |
Total | $ 7,039 | |
[1] | Includes $390 million due to ComEd and PECO financing trusts. |
Schedule I - Condensed Finan_10
Schedule I - Condensed Financial Information of Parent (Exelon Corporate) - Related Party Transactions - Summary of Related Party Transactions (Details) - USD ($) $ in Millions | 12 Months Ended | |||
Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||
Related Party Transaction [Line Items] | ||||
Equity in earnings (losses) of unconsolidated affiliates | $ (28) | $ (32) | $ (24) | |
Payables to affiliates, current | 5 | 5 | ||
Exelon Corporate [Member] | ||||
Related Party Transaction [Line Items] | ||||
Operating and maintenance from affiliates | [1] | 9 | 25 | 51 |
Interest income from affiliates, net | 42 | 40 | 39 | |
Equity in earnings (losses) of unconsolidated affiliates | 2,188 | 4,414 | 1,508 | |
Cash contributions received from affiliates | 2,302 | 1,879 | 1,912 | |
Accounts receivable from affiliates, current | 44 | 33 | ||
Note receivable from affiliates, current | 216 | 217 | ||
Investments in affiliates | 40,448 | 39,311 | ||
Notes receivable from affiliates, noncurrent | 898 | 910 | ||
Payables to affiliates, current | 360 | 360 | ||
Exelon Corporate [Member] | Exelon Business Services Co Affiliate [Member] | ||||
Related Party Transaction [Line Items] | ||||
Operating and maintenance from affiliates | [1] | 11 | 23 | 51 |
Interest income from affiliates, net | 4 | 3 | 0 | |
Equity in earnings (losses) of unconsolidated affiliates | 0 | 1 | 1 | |
Accounts receivable from affiliates, current | [1] | 13 | 1 | |
Note receivable from affiliates, current | [1] | 116 | 217 | |
Investments in affiliates | [1] | 197 | 196 | |
Exelon Corporate [Member] | Other Affiliate [Member] | ||||
Related Party Transaction [Line Items] | ||||
Operating and maintenance from affiliates | (2) | 2 | 0 | |
Investments in affiliates | (6) | (6) | ||
Exelon Corporate [Member] | Exelon Generation Co L L C [Member] | ||||
Related Party Transaction [Line Items] | ||||
Interest income from affiliates, net | 36 | 37 | 39 | |
Equity in earnings (losses) of unconsolidated affiliates | 369 | 2,710 | 483 | |
Accounts receivable from affiliates, current | 17 | 21 | ||
Note receivable from affiliates, current | [2] | 100 | 0 | |
Investments in affiliates | 13,204 | 13,674 | ||
Notes receivable from affiliates, noncurrent | [2] | 898 | 910 | |
Exelon Corporate [Member] | Commonwealth Edison Co [Member] | ||||
Related Party Transaction [Line Items] | ||||
Accounts receivable from affiliates, current | 4 | 3 | ||
Exelon Corporate [Member] | PECO Energy Co [Member] | ||||
Related Party Transaction [Line Items] | ||||
Accounts receivable from affiliates, current | 2 | 1 | ||
Exelon Corporate [Member] | Baltimore Gas and Electric Company [Member] | ||||
Related Party Transaction [Line Items] | ||||
Accounts receivable from affiliates, current | 2 | 1 | ||
Exelon Corporate [Member] | PHI Service Co Affiliate [Member] | ||||
Related Party Transaction [Line Items] | ||||
Accounts receivable from affiliates, current | 6 | 6 | ||
Exelon Corporate [Member] | Exelon Energy Delivery Company LLC [Member] | ||||
Related Party Transaction [Line Items] | ||||
Interest income from affiliates, net | [3] | 2 | 0 | 0 |
Equity in earnings (losses) of unconsolidated affiliates | [3] | 1,835 | 1,670 | 1,041 |
Investments in affiliates | [3] | 26,702 | 25,082 | |
Exelon Corporate [Member] | Potomac Capital Investment Affiliate [Member] | ||||
Related Party Transaction [Line Items] | ||||
Equity in earnings (losses) of unconsolidated affiliates | (17) | 1 | 6 | |
Investments in affiliates | 61 | 78 | ||
Exelon Corporate [Member] | UII LLC [Member] | ||||
Related Party Transaction [Line Items] | ||||
Equity in earnings (losses) of unconsolidated affiliates | 0 | 41 | (9) | |
Investments in affiliates | 268 | 268 | ||
Payables to affiliates, current | 360 | 360 | ||
Exelon Corporate [Member] | Exelon Transmission Company LLC [Member] | ||||
Related Party Transaction [Line Items] | ||||
Equity in earnings (losses) of unconsolidated affiliates | 1 | (10) | (13) | |
Investments in affiliates | 1 | 1 | ||
Exelon Corporate [Member] | VEBA [Member] | ||||
Related Party Transaction [Line Items] | ||||
Investments in affiliates | (1) | (4) | ||
Exelon Corporate [Member] | Exelon Enterprise [Member] | ||||
Related Party Transaction [Line Items] | ||||
Equity in earnings (losses) of unconsolidated affiliates | 0 | 1 | $ (1) | |
Investments in affiliates | $ 22 | $ 22 | ||
[1] | Exelon Corporate receives a variety of corporate support services from BSC, including legal, human resources, financial, information technology and supply management services. All services are provided at cost, including applicable overhead. | |||
[2] | In connection with the debt obligations assumed by Exelon as part of the Constellation merger, Exelon and subsidiaries of Generation (former Constellation subsidiaries) assumed intercompany loan agreements that mirror the terms and amounts of the third-party debt obligations of Exelon, resulting in intercompany notes payable included in Long-Term Debt to affiliates in Generation’s Consolidated Balance Sheets and intercompany notes receivable at Exelon Corporate, which are eliminated in consolidation in Exelon’s Consolidated Balance Sheets. | |||
[3] | Exelon Energy Delivery Company, LLC consists of ComEd, PECO, BGE, PHI, Pepco, DPL and ACE. |
Schedule II - Valuation and Q_2
Schedule II - Valuation and Qualifying Accounts Schedule II - Valuation and Qualifying Accounts (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |||||
Mar. 23, 2016 | Dec. 31, 2016 | Dec. 31, 2018 | Dec. 31, 2017 | Dec. 31, 2016 | ||||
Allowance for Uncollectible Accounts [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | [1] | $ 284 | $ 322 | $ 334 | $ 284 | |||
Charged to Costs and Expenses | [1] | 159 | 126 | 162 | ||||
Charged to Other Accounts | [1],[2] | 35 | 27 | 99 | [3] | |||
Deductions | [1],[4] | 197 | 165 | 211 | ||||
Balance at End of Period | [1] | $ 334 | 319 | 322 | 334 | |||
Deferred Tax Valuation Allowance [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 13 | 37 | 20 | 13 | ||||
Charged to Costs and Expenses | 0 | 0 | 0 | |||||
Charged to Other Accounts | 5 | 17 | 10 | [3] | ||||
Deductions | 7 | 0 | 3 | |||||
Balance at End of Period | 20 | 35 | 37 | 20 | ||||
Reserve for Obsolete Materials [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 105 | 174 | 113 | 105 | ||||
Charged to Costs and Expenses | 25 | 56 | 12 | |||||
Charged to Other Accounts | (31) | [5] | 10 | 1 | [3] | |||
Deductions | 12 | 5 | 5 | |||||
Balance at End of Period | 113 | 156 | 174 | 113 | ||||
Exelon Generation Co L L C [Member] | Allowance for Uncollectible Accounts [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 77 | 114 | 91 | 77 | ||||
Charged to Costs and Expenses | 44 | 34 | 19 | |||||
Charged to Other Accounts | 4 | 0 | 3 | |||||
Deductions | 58 | 11 | 8 | |||||
Balance at End of Period | 91 | 104 | 114 | 91 | ||||
Exelon Generation Co L L C [Member] | Deferred Tax Valuation Allowance [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 11 | 23 | 9 | 11 | ||||
Charged to Costs and Expenses | 0 | 0 | 0 | |||||
Charged to Other Accounts | 3 | 14 | 0 | |||||
Deductions | 0 | 0 | 2 | |||||
Balance at End of Period | 9 | 26 | 23 | 9 | ||||
Exelon Generation Co L L C [Member] | Reserve for Obsolete Materials [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 102 | 166 | 106 | 102 | ||||
Charged to Costs and Expenses | 20 | 51 | 6 | |||||
Charged to Other Accounts | (32) | [6] | 9 | 0 | ||||
Deductions | 9 | 0 | 2 | |||||
Balance at End of Period | 106 | 145 | 166 | 106 | ||||
Commonwealth Edison Co [Member] | Allowance for Uncollectible Accounts [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 75 | 73 | 70 | 75 | ||||
Charged to Costs and Expenses | 44 | 39 | 45 | |||||
Charged to Other Accounts | [7] | 23 | 20 | 23 | ||||
Deductions | [8] | 59 | 56 | 73 | ||||
Balance at End of Period | 70 | 81 | 73 | 70 | ||||
Commonwealth Edison Co [Member] | Reserve for Obsolete Materials [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 3 | 5 | 4 | 3 | ||||
Charged to Costs and Expenses | 3 | 3 | 4 | |||||
Charged to Other Accounts | 1 | 1 | 1 | |||||
Deductions | 3 | 3 | 4 | |||||
Balance at End of Period | 4 | 6 | 5 | 4 | ||||
PECO Energy Co [Member] | Allowance for Uncollectible Accounts [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | [9] | 83 | 56 | 61 | 83 | |||
Charged to Costs and Expenses | [9] | 33 | 26 | 32 | ||||
Charged to Other Accounts | [9],[10] | 3 | 4 | 7 | ||||
Deductions | [9],[11] | 31 | 35 | 61 | ||||
Balance at End of Period | [9] | 61 | 61 | 56 | 61 | |||
PECO Energy Co [Member] | Reserve for Obsolete Materials [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 1 | 2 | 2 | 1 | ||||
Charged to Costs and Expenses | 0 | 0 | 1 | |||||
Charged to Other Accounts | 0 | 0 | 0 | |||||
Deductions | 0 | 0 | 0 | |||||
Balance at End of Period | 2 | 2 | 2 | 2 | ||||
PECO Energy Co [Member] | Allowance for Doubtful Accounts, Noncurrent [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 15 | 23 | ||||||
Balance at End of Period | 23 | 13 | 15 | 23 | ||||
Baltimore Gas and Electric Company [Member] | Allowance for Uncollectible Accounts [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 49 | 24 | 32 | 49 | ||||
Charged to Costs and Expenses | 10 | 8 | 1 | |||||
Charged to Other Accounts | (2) | (3) | 9 | |||||
Deductions | [12] | 12 | 13 | 27 | ||||
Balance at End of Period | 32 | 20 | 24 | 32 | ||||
Baltimore Gas and Electric Company [Member] | Deferred Tax Valuation Allowance [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 1 | 1 | 1 | 1 | ||||
Charged to Costs and Expenses | 0 | 0 | 0 | |||||
Charged to Other Accounts | 0 | 0 | 0 | |||||
Deductions | 0 | 0 | 0 | |||||
Balance at End of Period | 1 | 1 | 1 | 1 | ||||
Baltimore Gas and Electric Company [Member] | Reserve for Obsolete Materials [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 0 | 0 | 0 | 0 | ||||
Charged to Costs and Expenses | 1 | 0 | 0 | |||||
Charged to Other Accounts | 0 | 0 | 0 | |||||
Deductions | 0 | 0 | 0 | |||||
Balance at End of Period | 0 | 1 | 0 | 0 | ||||
Pepco Holdings LLC [Member] | Allowance for Uncollectible Accounts [Member] | Successor [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 52 | 55 | 80 | |||||
Charged to Costs and Expenses | 65 | 28 | 19 | |||||
Charged to Other Accounts | [13] | 5 | 7 | 6 | ||||
Deductions | [14] | 42 | 37 | 50 | ||||
Balance at End of Period | 52 | 80 | 53 | 55 | 80 | |||
Pepco Holdings LLC [Member] | Allowance for Uncollectible Accounts [Member] | Predecessor [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 56 | 52 | 56 | |||||
Charged to Costs and Expenses | 16 | |||||||
Charged to Other Accounts | [13] | 2 | ||||||
Deductions | [14] | 22 | ||||||
Balance at End of Period | 52 | |||||||
Pepco Holdings LLC [Member] | Deferred Tax Valuation Allowance [Member] | Successor [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 63 | 13 | 10 | |||||
Charged to Costs and Expenses | 0 | 0 | 0 | |||||
Charged to Other Accounts | (53) | 2 | 3 | |||||
Deductions | 0 | 7 | 0 | |||||
Balance at End of Period | 63 | 10 | 8 | 13 | 10 | |||
Pepco Holdings LLC [Member] | Deferred Tax Valuation Allowance [Member] | Predecessor [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 63 | 63 | 63 | |||||
Charged to Costs and Expenses | 0 | |||||||
Charged to Other Accounts | 0 | |||||||
Deductions | 0 | |||||||
Balance at End of Period | 63 | |||||||
Pepco Holdings LLC [Member] | Reserve for Obsolete Materials [Member] | Successor [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 0 | 2 | 2 | |||||
Charged to Costs and Expenses | 1 | 0 | 2 | |||||
Charged to Other Accounts | 0 | 0 | 0 | |||||
Deductions | (1) | 0 | 2 | |||||
Balance at End of Period | 0 | 2 | 2 | 2 | 2 | |||
Pepco Holdings LLC [Member] | Reserve for Obsolete Materials [Member] | Predecessor [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 0 | 0 | 0 | |||||
Charged to Costs and Expenses | 0 | |||||||
Charged to Other Accounts | 0 | |||||||
Deductions | 0 | |||||||
Balance at End of Period | 0 | |||||||
Potomac Electric Power Company [Member] | Allowance for Uncollectible Accounts [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 17 | 21 | 29 | 17 | ||||
Charged to Costs and Expenses | 11 | 8 | 29 | |||||
Charged to Other Accounts | [15] | 3 | 2 | 3 | ||||
Deductions | [16] | 14 | 18 | 20 | ||||
Balance at End of Period | 29 | 21 | 21 | 29 | ||||
Potomac Electric Power Company [Member] | Reserve for Obsolete Materials [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 0 | 1 | 1 | 0 | ||||
Charged to Costs and Expenses | 0 | 1 | 3 | |||||
Charged to Other Accounts | 0 | 0 | 0 | |||||
Deductions | 0 | 1 | 2 | |||||
Balance at End of Period | 1 | 1 | 1 | 1 | ||||
Delmarva Power & Light Company [Member] | Allowance for Uncollectible Accounts [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 17 | 16 | 24 | 17 | ||||
Charged to Costs and Expenses | 6 | 3 | 23 | |||||
Charged to Other Accounts | [17] | 2 | 2 | 2 | ||||
Deductions | [18] | 11 | 13 | 18 | ||||
Balance at End of Period | 24 | 13 | 16 | 24 | ||||
Delmarva Power & Light Company [Member] | Reserve for Obsolete Materials [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 0 | 0 | 0 | 0 | ||||
Charged to Costs and Expenses | 0 | 1 | 1 | |||||
Charged to Other Accounts | 0 | 0 | 0 | |||||
Deductions | 0 | 1 | 1 | |||||
Balance at End of Period | 0 | 0 | 0 | 0 | ||||
Atlantic City Electric Company [Member] | Allowance for Uncollectible Accounts [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | 17 | 18 | 27 | 17 | ||||
Charged to Costs and Expenses | 11 | 8 | 32 | |||||
Charged to Other Accounts | [19] | 2 | 2 | 2 | ||||
Deductions | [20] | 12 | 19 | 24 | ||||
Balance at End of Period | 27 | 19 | 18 | 27 | ||||
Atlantic City Electric Company [Member] | Reserve for Obsolete Materials [Member] | ||||||||
Movement in Valuation Allowances and Reserves [Roll Forward] | ||||||||
Balance at Beginning of Period | $ 0 | 1 | 1 | 0 | ||||
Charged to Costs and Expenses | 0 | 0 | 1 | |||||
Charged to Other Accounts | 0 | 0 | 0 | |||||
Deductions | 0 | 0 | 0 | |||||
Balance at End of Period | $ 1 | $ 1 | $ 1 | $ 1 | ||||
[1] | Excludes the non-current allowance for uncollectible accounts related to PECO’s installment plan receivables of $13 million, $15 million, and $23 million for the years ended December 31, 2018, 2017 and 2016, respectively. | |||||||
[2] | Includes charges for late payments and non-service receivables | |||||||
[3] | Primarily represents the addition of PHI's results as of March 23, 2016, the date of the merger | |||||||
[4] | Write-off of individual accounts receivable. | |||||||
[5] | Primarily reflects the reclassification of assets as held for sale. | |||||||
[6] | Primarily reflects the reclassification of assets as held for sale. | |||||||
[7] | Primarily charges for late payments and non-service receivables. | |||||||
[8] | Write-off of individual accounts receivable. | |||||||
[9] | Excludes the non-current allowance for uncollectible accounts related to PECO’s installment plan receivables of $13 million, $15 million, and $23 million for the years ended December 31, 2018, 2017, and 2016, respectively. | |||||||
[10] | Primarily charges for late payments. | |||||||
[11] | Write-off of individual accounts receivable. | |||||||
[12] | Write-off of individual accounts receivable. | |||||||
[13] | Primarily charges for late payments. | |||||||
[14] | Write-off of individual accounts receivable. | |||||||
[15] | Primarily charges for late payments. | |||||||
[16] | Write-off of individual accounts receivable. | |||||||
[17] | Primarily charges for late payments. | |||||||
[18] | Write-off of individual accounts receivable. | |||||||
[19] | Primarily charges for late payments. | |||||||
[20] | Write-off of individual accounts receivable. |
Uncategorized Items - exc-20181
Label | Element | Value |
Pepco Holdings LLC [Member] | Predecessor [Member] | ||
Proceeds from Stock Plans | us-gaap_ProceedsFromStockPlans | $ 2,000,000 |
Cash and Cash Equivalents, Period Increase (Decrease) | us-gaap_CashAndCashEquivalentsPeriodIncreaseDecrease | 290,000,000 |
Repayments of Short-term Debt, Maturing in More than Three Months | us-gaap_RepaymentsOfShortTermDebtMaturingInMoreThanThreeMonths | 0 |
Impairment of Long-Lived Assets Held-for-use | us-gaap_ImpairmentOfLongLivedAssetsHeldForUse | 0 |
Deferred Income Taxes and Tax Credits | us-gaap_DeferredIncomeTaxesAndTaxCredits | 19,000,000 |
Increase (Decrease) in Due to Affiliates, Current | us-gaap_IncreaseDecreaseInDueToAffiliatesCurrent | 0 |
Unrealized Gain (Loss) on Derivatives | us-gaap_UnrealizedGainLossOnDerivatives | 18,000,000 |
Proceeds from (Repayments of) Short-term Debt, Maturing in Three Months or Less | us-gaap_ProceedsFromRepaymentsOfShortTermDebtMaturingInThreeMonthsOrLess | (121,000,000) |
Other Noncash Income (Expense) | us-gaap_OtherNoncashIncomeExpense | 46,000,000 |
Net Cash Provided by (Used in) Operating Activities | us-gaap_NetCashProvidedByUsedInOperatingActivities | 264,000,000 |
Net Cash Provided by (Used in) Financing Activities | us-gaap_NetCashProvidedByUsedInFinancingActivities | 372,000,000 |
Increase (Decrease) in Inventories | us-gaap_IncreaseDecreaseInInventories | (4,000,000) |
Increase (Decrease) in Receivables | us-gaap_IncreaseDecreaseInReceivables | (28,000,000) |
Proceeds from Contributions from Parent | us-gaap_ProceedsFromContributionsFromParent | 0 |
Proceeds from Short-term Debt, Maturing in More than Three Months | us-gaap_ProceedsFromShortTermDebtMaturingInMoreThanThreeMonths | 500,000,000 |
Repayments of Long-term Debt | us-gaap_RepaymentsOfLongTermDebt | 11,000,000 |
Increase (Decrease) in Accounts Payable and Accrued Liabilities | us-gaap_IncreaseDecreaseInAccountsPayableAndAccruedLiabilities | 42,000,000 |
Payments for (Proceeds from) Other Investing Activities | us-gaap_PaymentsForProceedsFromOtherInvestingActivities | 5,000,000 |
Payments of Distributions to Affiliates | us-gaap_PaymentsOfDistributionsToAffiliates | 0 |
Proceeds from (Payments for) Other Financing Activities | us-gaap_ProceedsFromPaymentsForOtherFinancingActivities | 2,000,000 |
Payments to Acquire Marketable Securities | us-gaap_PaymentsToAcquireMarketableSecurities | 68,000,000 |
Increase (Decrease) in Other Operating Assets and Liabilities, Net | us-gaap_IncreaseDecreaseInOtherOperatingCapitalNet | (8,000,000) |
Proceeds from Issuance of Long-term Debt | us-gaap_ProceedsFromIssuanceOfLongTermDebt | 0 |
Change Receivables Payables From Affiliates | exc_ChangeReceivablesPayablesFromAffiliates | 0 |
Increase (Decrease) in Income Taxes Payable | us-gaap_IncreaseDecreaseInAccruedIncomeTaxesPayable | 12,000,000 |
Net Cash Provided by (Used in) Investing Activities | us-gaap_NetCashProvidedByUsedInInvestingActivities | (346,000,000) |
Pepco Holdings LLC [Member] | Successor [Member] | ||
Proceeds from Stock Plans | us-gaap_ProceedsFromStockPlans | 0 |
Cash and Cash Equivalents, Period Increase (Decrease) | us-gaap_CashAndCashEquivalentsPeriodIncreaseDecrease | (112,000,000) |
Repayments of Short-term Debt, Maturing in More than Three Months | us-gaap_RepaymentsOfShortTermDebtMaturingInMoreThanThreeMonths | 300,000,000 |
Deferred Income Taxes and Tax Credits | us-gaap_DeferredIncomeTaxesAndTaxCredits | 295,000,000 |
Increase (Decrease) in Due to Affiliates, Current | us-gaap_IncreaseDecreaseInDueToAffiliatesCurrent | (6,000,000) |
Unrealized Gain (Loss) on Derivatives | us-gaap_UnrealizedGainLossOnDerivatives | 0 |
Proceeds from (Repayments of) Short-term Debt, Maturing in Three Months or Less | us-gaap_ProceedsFromRepaymentsOfShortTermDebtMaturingInThreeMonthsOrLess | (515,000,000) |
Other Noncash Income (Expense) | us-gaap_OtherNoncashIncomeExpense | 515,000,000 |
Net Cash Provided by (Used in) Operating Activities | us-gaap_NetCashProvidedByUsedInOperatingActivities | 888,000,000 |
Net Cash Provided by (Used in) Financing Activities | us-gaap_NetCashProvidedByUsedInFinancingActivities | (7,000,000) |
Increase (Decrease) in Inventories | us-gaap_IncreaseDecreaseInInventories | 3,000,000 |
Increase (Decrease) in Receivables | us-gaap_IncreaseDecreaseInReceivables | (21,000,000) |
Proceeds from Short-term Debt, Maturing in More than Three Months | us-gaap_ProceedsFromShortTermDebtMaturingInMoreThanThreeMonths | 0 |
Repayments of Long-term Debt | us-gaap_RepaymentsOfLongTermDebt | 338,000,000 |
Increase (Decrease) in Accounts Payable and Accrued Liabilities | us-gaap_IncreaseDecreaseInAccountsPayableAndAccruedLiabilities | 19,000,000 |
Payments for (Proceeds from) Other Investing Activities | us-gaap_PaymentsForProceedsFromOtherInvestingActivities | (15,000,000) |
Proceeds from (Payments for) Other Financing Activities | us-gaap_ProceedsFromPaymentsForOtherFinancingActivities | (5,000,000) |
Payments to Acquire Marketable Securities | us-gaap_PaymentsToAcquireMarketableSecurities | 0 |
Increase (Decrease) in Other Operating Assets and Liabilities, Net | us-gaap_IncreaseDecreaseInOtherOperatingCapitalNet | (311,000,000) |
Proceeds from Issuance of Long-term Debt | us-gaap_ProceedsFromIssuanceOfLongTermDebt | 179,000,000 |
Change Receivables Payables From Affiliates | exc_ChangeReceivablesPayablesFromAffiliates | 42,000,000 |
Increase (Decrease) in Income Taxes Payable | us-gaap_IncreaseDecreaseInAccruedIncomeTaxesPayable | (22,000,000) |
Net Cash Provided by (Used in) Investing Activities | us-gaap_NetCashProvidedByUsedInInvestingActivities | $ (993,000,000) |