Document and Entity Information
Document and Entity Information - shares | 9 Months Ended | |
Sep. 30, 2015 | Oct. 20, 2015 | |
Entity Information [Line Items] | ||
Document Type | 10-Q | |
Amendment Flag | false | |
Document Period End Date | Sep. 30, 2015 | |
Document Fiscal Year Focus | 2,015 | |
Document Fiscal Period Focus | Q3 | |
Trading Symbol | PEG | |
Entity Registrant Name | PUBLIC SERVICE ENTERPRISE GROUP INC | |
Entity Central Index Key | 788,784 | |
Current Fiscal Year End Date | --12-31 | |
Entity Filer Category | Large Accelerated Filer | |
Entity Common Stock, Shares Outstanding | 505,961,856 | |
PSE And G [Member] | ||
Entity Information [Line Items] | ||
Document Type | 10-Q | |
Amendment Flag | false | |
Document Period End Date | Sep. 30, 2015 | |
Document Fiscal Year Focus | 2,015 | |
Document Fiscal Period Focus | Q3 | |
Entity Registrant Name | PUBLIC SERVICE ELECTRIC & GAS CO | |
Entity Central Index Key | 81,033 | |
Current Fiscal Year End Date | --12-31 | |
Entity Filer Category | Non-accelerated Filer | |
Entity Common Stock, Shares Outstanding | 132,450,344 | |
Power [Member] | ||
Entity Information [Line Items] | ||
Document Type | 10-Q | |
Amendment Flag | false | |
Document Period End Date | Sep. 30, 2015 | |
Document Fiscal Year Focus | 2,015 | |
Document Fiscal Period Focus | Q3 | |
Entity Registrant Name | PSEG POWER LLC | |
Entity Central Index Key | 1,158,659 | |
Current Fiscal Year End Date | --12-31 | |
Entity Filer Category | Non-accelerated Filer |
Condensed Consolidated Statemen
Condensed Consolidated Statements Of Operations - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Operating Revenues | $ 2,688 | $ 2,641 | $ 8,137 | $ 8,113 |
Operating Expenses [Abstract] | ||||
Energy Costs | 815 | 863 | 2,577 | 3,008 |
Operation and Maintenance | 746 | 714 | 2,170 | 2,370 |
Depreciation and Amortization | 313 | 318 | 960 | 919 |
Total Operating Expenses | 1,874 | 1,895 | 5,707 | 6,297 |
OPERATING INCOME | 814 | 746 | 2,430 | 1,816 |
Income from Equity Method Investments | 3 | 3 | 10 | 10 |
Other Income | 47 | 75 | 171 | 185 |
Other Deductions | (14) | (9) | (36) | (31) |
Other-Than-Temporary Impairments | (30) | (10) | (45) | (14) |
Interest Expense | (96) | (100) | (291) | (291) |
INCOME BEFORE INCOME TAXES | 724 | 705 | 2,239 | 1,675 |
Income Tax Expense | (285) | (261) | (869) | (633) |
Net Income | $ 439 | $ 444 | $ 1,370 | $ 1,042 |
WEIGHTED AVERAGE COMMON SHARES OUTSTANDING: | ||||
BASIC (in shares) | 505 | 506 | 505 | 506 |
DILUTED (in shares) | 508 | 507 | 508 | 507 |
EARNINGS PER SHARE: | ||||
BASIC (in dollars per share) | $ 0.87 | $ 0.88 | $ 2.71 | $ 2.06 |
DILUTED (in dollars per share) | 0.87 | 0.87 | 2.70 | 2.05 |
DIVIDENDS PAID PER SHARE OF COMMON STOCK (in dollars per share) | $ 0.39 | $ 0.37 | $ 1.17 | $ 1.11 |
PSE And G [Member] | ||||
Operating Revenues | $ 1,766 | $ 1,655 | $ 5,234 | $ 5,235 |
Operating Expenses [Abstract] | ||||
Energy Costs | 740 | 668 | 2,176 | 2,278 |
Operation and Maintenance | 391 | 366 | 1,171 | 1,190 |
Depreciation and Amortization | 231 | 238 | 712 | 682 |
Total Operating Expenses | 1,362 | 1,272 | 4,059 | 4,150 |
OPERATING INCOME | 404 | 383 | 1,175 | 1,085 |
Other Income | 22 | 16 | 59 | 44 |
Other Deductions | 0 | (2) | (2) | (3) |
Interest Expense | (67) | (71) | (203) | (206) |
INCOME BEFORE INCOME TAXES | 359 | 326 | 1,029 | 920 |
Income Tax Expense | (137) | (126) | (398) | (355) |
Net Income | 222 | 200 | 631 | 565 |
Power [Member] | ||||
Operating Revenues | 1,096 | 1,138 | 3,846 | 3,824 |
Operating Expenses [Abstract] | ||||
Energy Costs | 367 | 472 | 1,669 | 2,036 |
Operation and Maintenance | 263 | 242 | 748 | 871 |
Depreciation and Amortization | 75 | 71 | 226 | 215 |
Total Operating Expenses | 705 | 785 | 2,643 | 3,122 |
OPERATING INCOME | 391 | 353 | 1,203 | 702 |
Income from Equity Method Investments | 3 | 4 | 11 | 11 |
Other Income | 25 | 56 | 109 | 135 |
Other Deductions | (14) | (6) | (32) | (25) |
Other-Than-Temporary Impairments | (30) | (10) | (45) | (14) |
Interest Expense | (30) | (31) | (94) | (92) |
INCOME BEFORE INCOME TAXES | 345 | 366 | 1,152 | 717 |
Income Tax Expense | (139) | (144) | (445) | (277) |
Net Income | $ 206 | $ 222 | $ 707 | $ 440 |
Condensed Consolidated Stateme3
Condensed Consolidated Statements Of Comprehensive Income - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Net Income | $ 439 | $ 444 | $ 1,370 | $ 1,042 |
Other Comprehensive Income (Loss), net of tax | ||||
Unrealized Gains (Losses) on Available-for-Sale Securities, net of tax (expense) benefit | (31) | (30) | (32) | (17) |
Unrealized Gains (Losses) on Cash Flow Hedges, net of tax (expense) benefit | 0 | 1 | (9) | 4 |
Pension/OPEB adjustment, net of tax (expense) benefit | 9 | 3 | 25 | 9 |
Other Comprehensive Income (Loss), net of tax | (22) | (26) | (16) | (4) |
COMPREHENSIVE INCOME | 417 | 418 | 1,354 | 1,038 |
PSE And G [Member] | ||||
Net Income | 222 | 200 | 631 | 565 |
Other Comprehensive Income (Loss), net of tax | ||||
Unrealized Gains (Losses) on Available-for-Sale Securities, net of tax (expense) benefit | 0 | 1 | (1) | 1 |
COMPREHENSIVE INCOME | 222 | 201 | 630 | 566 |
Power [Member] | ||||
Net Income | 206 | 222 | 707 | 440 |
Other Comprehensive Income (Loss), net of tax | ||||
Unrealized Gains (Losses) on Available-for-Sale Securities, net of tax (expense) benefit | (29) | (30) | (29) | (19) |
Unrealized Gains (Losses) on Cash Flow Hedges, net of tax (expense) benefit | 0 | 1 | (9) | 4 |
Pension/OPEB adjustment, net of tax (expense) benefit | 7 | 2 | 21 | 7 |
Other Comprehensive Income (Loss), net of tax | (22) | (27) | (17) | (8) |
COMPREHENSIVE INCOME | $ 184 | $ 195 | $ 690 | $ 432 |
Condensed Consolidated Stateme4
Condensed Consolidated Statements Of Comprehensive Income (Parenthetical) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Unrealized Gains (Losses) on Available-for-Sale Securities, tax | $ 33 | $ 33 | $ 35 | $ 21 |
Unrealized Gains (Losses) on Cash Flow Hedges, tax | (1) | (1) | 6 | (3) |
Pension/OPEB adjustment, tax | (5) | (2) | (17) | (5) |
PSE And G [Member] | ||||
Unrealized Gains (Losses) on Available-for-Sale Securities, tax | 0 | 0 | 0 | 0 |
Power [Member] | ||||
Unrealized Gains (Losses) on Available-for-Sale Securities, tax | 32 | 34 | 33 | 23 |
Unrealized Gains (Losses) on Cash Flow Hedges, tax | (1) | 0 | 6 | (2) |
Pension/OPEB adjustment, tax | $ (5) | $ (1) | $ (15) | $ (4) |
Condensed Consolidated Balance
Condensed Consolidated Balance Sheets - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 | |
CURRENT ASSETS | |||
Cash and Cash Equivalents | $ 271 | $ 402 | |
Accounts Receivable, net of allowances | 1,199 | 1,254 | |
Tax Receivable | 5 | 211 | |
Unbilled Revenues | 203 | 284 | |
Fuel | 451 | 538 | |
Materials and Supplies, net | 472 | 484 | |
Prepayments | 180 | 108 | |
Derivative Contracts | 162 | 240 | |
Deferred Income Taxes | 23 | 11 | |
Regulatory Assets | 189 | 323 | |
Regulatory Assets of Consolidated Variable Interest Entity Current | 0 | 249 | |
Restricted Cash of VIEs | 26 | 0 | |
Other | 23 | 15 | |
Total Current Assets | 3,204 | 4,119 | |
PROPERTY, PLANT AND EQUIPMENT | 34,625 | 32,196 | |
Less: Accumulated Depreciation and Amortization | (9,020) | (8,607) | |
Net Property, Plant and Equipment | 25,605 | 23,589 | |
NONCURRENT ASSETS | |||
Regulatory Assets | 3,161 | 3,192 | |
Long-Term Investments | 1,235 | 1,307 | |
Nuclear Decommissioning Trust (NDT) Fund | 1,715 | 1,780 | |
Long-Term Tax Receivable | 165 | 64 | |
Long-Term Receivable of VIE | 601 | 580 | |
Other Special Funds | 230 | 212 | |
Goodwill | 16 | 16 | |
Other Intangibles | 122 | 84 | |
Derivative Contracts | 91 | 77 | |
Restricted Cash of VIEs | 0 | 24 | |
Other | 279 | 289 | |
Total Noncurrent Assets | 7,615 | 7,625 | |
Total Assets | 36,424 | 35,333 | |
CURRENT LIABILITIES | |||
Long-Term Debt Due Within One Year | 1,038 | 624 | |
Securitization Debt of VIEs Due Within One Year | 68 | 259 | |
Commercial Paper | 20 | 0 | |
Accounts Payable | 1,046 | 1,178 | |
Derivative Contracts | 70 | 132 | |
Accrued Interest | 123 | 95 | |
Accrued Taxes | 204 | 21 | |
Deferred Income Taxes | 0 | 173 | |
Clean Energy Program | 185 | 142 | |
Obligation to Return Cash Collateral | 126 | 121 | |
Regulatory Liabilities | 208 | 186 | |
Regulatory Liabilities of Consolidated Variable Interest Entity, Current | 3 | 0 | |
Other | 513 | 547 | |
Total Current Liabilities | 3,604 | 3,478 | |
NONCURRENT LIABILITIES | |||
Deferred Income Taxes and Investment Tax Credits (ITC) | 7,672 | 7,303 | |
Regulatory Liabilities | 181 | 258 | |
Regulatory Liabilities of VIEs | 0 | 39 | |
Asset Retirement Obligations | 776 | 743 | |
Other Postretirement Benefit (OPEB) Costs | 1,250 | 1,277 | |
OPEB Costs of Servco | 480 | 452 | |
Accrued Pension Costs | 373 | 440 | |
Accrued Pension Costs of Servco | 118 | 126 | |
Environmental Costs | 438 | 417 | |
Derivative Contracts | 23 | 33 | |
Long-Term Accrued Taxes | 287 | 208 | |
Other | 156 | 112 | |
Total Noncurrent Liabilities | $ 11,754 | $ 11,408 | |
COMMITMENTS AND CONTINGENT LIABILITIES | |||
LONG-TERM DEBT | |||
Total Long-Term Debt | $ 8,132 | $ 8,261 | |
STOCKHOLDER'S EQUITY | |||
Common Stock | 4,894 | 4,876 | |
Treasury Stock, at cost | (667) | (635) | |
Retained Earnings | 9,005 | 8,227 | |
Accumulated Other Comprehensive Income (Loss) | (299) | (283) | |
Total Common Stockholders' Equity | 12,933 | 12,185 | |
Noncontrolling Interest | 1 | 1 | |
Total Stockholder's Equity | 12,934 | 12,186 | |
Total Capitalization | 21,066 | 20,447 | |
TOTAL LIABILITIES AND CAPITALIZATION | 36,424 | 35,333 | |
PSE And G [Member] | |||
CURRENT ASSETS | |||
Cash and Cash Equivalents | 14 | 310 | |
Accounts Receivable, net of allowances | 938 | 864 | |
Accounts Receivable-Affiliated Companies | 7 | 274 | |
Unbilled Revenues | 203 | 284 | |
Materials and Supplies, net | 146 | 133 | |
Prepayments | 109 | 42 | |
Derivative Contracts | 4 | 18 | |
Deferred Income Taxes | 47 | 24 | |
Regulatory Assets | 189 | 323 | |
Regulatory Assets of Consolidated Variable Interest Entity Current | 0 | 249 | |
Restricted Cash of VIEs | 26 | 0 | |
Other | 17 | 7 | |
Total Current Assets | 1,700 | 2,528 | |
PROPERTY, PLANT AND EQUIPMENT | 22,940 | 21,103 | |
Less: Accumulated Depreciation and Amortization | (5,419) | (5,183) | |
Net Property, Plant and Equipment | 17,521 | 15,920 | |
NONCURRENT ASSETS | |||
Regulatory Assets | 3,161 | 3,192 | |
Long-Term Investments | 335 | 348 | |
Other Special Funds | 52 | 53 | |
Derivative Contracts | 0 | 8 | |
Restricted Cash of VIEs | 0 | 24 | |
Other | 140 | 150 | |
Total Noncurrent Assets | 3,688 | 3,775 | |
Total Assets | 22,909 | 22,223 | |
CURRENT LIABILITIES | |||
Long-Term Debt Due Within One Year | 171 | 300 | |
Securitization Debt of VIEs Due Within One Year | 68 | 259 | |
Commercial Paper | 20 | 0 | |
Accounts Payable | 567 | 574 | |
Accounts Payable-Affiliated Companies | 208 | 379 | |
Accrued Interest | 80 | 68 | |
Deferred Income Taxes | 0 | 165 | |
Clean Energy Program | 185 | 142 | |
Obligation to Return Cash Collateral | 126 | 121 | |
Regulatory Liabilities | 208 | 186 | |
Regulatory Liabilities of Consolidated Variable Interest Entity, Current | 3 | 0 | |
Other | 357 | 381 | |
Total Current Liabilities | 1,993 | 2,575 | |
NONCURRENT LIABILITIES | |||
Deferred Income Taxes and Investment Tax Credits (ITC) | 4,896 | 4,575 | |
Regulatory Liabilities | 181 | 258 | |
Regulatory Liabilities of VIEs | 0 | 39 | |
Asset Retirement Obligations | 304 | 290 | |
Other Postretirement Benefit (OPEB) Costs | 929 | 967 | |
Accrued Pension Costs | 131 | 173 | |
Environmental Costs | 387 | 364 | |
Derivative Contracts | 7 | 0 | |
Long-Term Accrued Taxes | 165 | 116 | |
Other | 58 | 67 | |
Total Noncurrent Liabilities | $ 7,058 | $ 6,849 | |
COMMITMENTS AND CONTINGENT LIABILITIES | |||
LONG-TERM DEBT | |||
Total Long-Term Debt | $ 6,441 | $ 6,012 | |
STOCKHOLDER'S EQUITY | |||
Common Stock | 892 | 892 | |
Contributed Capital | 695 | 695 | |
Basis Adjustment | 986 | 986 | |
Retained Earnings | 4,843 | 4,212 | |
Accumulated Other Comprehensive Income (Loss) | 1 | 2 | |
Total Stockholder's Equity | 7,417 | 6,787 | |
Total Capitalization | 13,858 | 12,799 | |
TOTAL LIABILITIES AND CAPITALIZATION | 22,909 | 22,223 | |
Power [Member] | |||
CURRENT ASSETS | |||
Cash and Cash Equivalents | 15 | 9 | |
Accounts Receivable, net of allowances | 218 | 334 | |
Accounts Receivable-Affiliated Companies | 158 | 313 | |
Tax Receivable | 3 | 3 | |
Short-Term Loan to Affiliate | 865 | 584 | |
Fuel | 451 | 538 | |
Materials and Supplies, net | 324 | 350 | |
Prepayments | 36 | 17 | |
Derivative Contracts | [1] | 147 | 207 |
Other | 7 | 4 | |
Total Current Assets | 2,224 | 2,359 | |
PROPERTY, PLANT AND EQUIPMENT | 11,273 | 10,732 | |
Less: Accumulated Depreciation and Amortization | (3,366) | (3,217) | |
Net Property, Plant and Equipment | 7,907 | 7,515 | |
NONCURRENT ASSETS | |||
Long-Term Investments | 116 | 121 | |
Nuclear Decommissioning Trust (NDT) Fund | 1,715 | 1,780 | |
Other Special Funds | 56 | 49 | |
Goodwill | 16 | 16 | |
Other Intangibles | 122 | 84 | |
Derivative Contracts | [1] | 91 | 62 |
Other | 67 | 60 | |
Total Noncurrent Assets | 2,183 | 2,172 | |
Total Assets | 12,314 | 12,046 | |
CURRENT LIABILITIES | |||
Long-Term Debt Due Within One Year | 853 | 300 | |
Accounts Payable | 315 | 424 | |
Accounts Payable-Affiliated Companies | 117 | 118 | |
Derivative Contracts | [1] | 70 | 132 |
Accrued Interest | 43 | 27 | |
Deferred Income Taxes | 44 | 43 | |
Other | 132 | 140 | |
Total Current Liabilities | 1,574 | 1,184 | |
NONCURRENT LIABILITIES | |||
Deferred Income Taxes and Investment Tax Credits (ITC) | 2,148 | 2,065 | |
Asset Retirement Obligations | 469 | 450 | |
Other Postretirement Benefit (OPEB) Costs | 258 | 248 | |
Accrued Pension Costs | 134 | 153 | |
Derivative Contracts | [1] | 16 | 33 |
Long-Term Accrued Taxes | 54 | 41 | |
Other | 121 | 71 | |
Total Noncurrent Liabilities | $ 3,200 | $ 3,061 | |
COMMITMENTS AND CONTINGENT LIABILITIES | |||
LONG-TERM DEBT | |||
Total Long-Term Debt | $ 1,691 | $ 2,243 | |
STOCKHOLDER'S EQUITY | |||
Contributed Capital | 2,215 | 2,214 | |
Basis Adjustment | (986) | (986) | |
Retained Earnings | 4,865 | 4,558 | |
Accumulated Other Comprehensive Income (Loss) | (245) | (228) | |
Total Stockholder's Equity | 5,849 | 5,558 | |
TOTAL LIABILITIES AND CAPITALIZATION | $ 12,314 | $ 12,046 | |
[1] | Substantially all of Power's and PSEG's derivative instruments are contracts subject to master netting agreements. Contracts not subject to master netting or similar agreements are immaterial and did not have any collateral posted or received as of September 30, 2015 and December 31, 2014. PSE&G does not have any derivative contracts subject to master netting or similar agreements. |
Condensed Consolidated Balance6
Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Accounts Receivable, allowances | $ 59 | $ 52 |
Common Stock, issued | 533,556,660 | 533,556,660 |
Common Stock, authorized | 1,000,000,000 | 1,000,000,000 |
Treasury Stock, Shares | 28,238,912 | 27,720,068 |
PSE And G [Member] | ||
Accounts Receivable, allowances | $ 59 | $ 52 |
Common Stock, issued | 132,450,344 | 132,450,344 |
Common Stock, outstanding | 132,450,344 | 132,450,344 |
Common Stock, authorized | 150,000,000 | 150,000,000 |
Condensed Consolidated Stateme7
Condensed Consolidated Statements Of Cash Flows - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2015 | Sep. 30, 2014 | |
CASH FLOWS FROM OPERATING ACTIVITIES | ||
Net Income | $ 1,370 | $ 1,042 |
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities: | ||
Depreciation and Amortization | 960 | 919 |
Amortization of Nuclear Fuel | 162 | 151 |
Provision for Deferred Income Taxes and ITC | 230 | 103 |
Non-Cash Employee Benefit Plan Costs | 121 | 36 |
Leveraged Lease Income, Adjusted for Rents Received and Deferred Taxes | 6 | (30) |
Net Realized and Unrealized (Gains) Losses on Energy Contracts and Other Derivatives | (87) | 237 |
Change in Accrued Storm Costs | 15 | (3) |
Net Change in Other Regulatory Assets and Liabilities | 26 | 276 |
Cost of Removal | (82) | (68) |
Net Realized (Gains) Losses and (Income) Expense from NDT Fund | (2) | (99) |
Net Change in Certain Current Assets and Liabilities: | ||
Tax Receivable | (206) | (95) |
Accrued Taxes | 127 | 127 |
Margin Deposit | 142 | (173) |
Other Current Assets and Liabilities | 15 | (103) |
Employee Benefit Plan Funding and Related Payments | (87) | (76) |
Other | 106 | 102 |
Net Cash Provided By (Used In) Operating Activities | 3,228 | 2,536 |
CASH FLOWS FROM INVESTING ACTIVITIES | ||
Additions to Property, Plant and Equipment | (2,782) | (1,922) |
Proceeds from Sales of Capital Leases and Investments | 12 | 11 |
Proceeds from Sale of Available-for-Sale Securities | 1,120 | 1,224 |
Investments in Available-for-Sale Securities | (1,163) | (1,241) |
Other | (28) | (60) |
Net Cash Provided By (Used In) Investing Activities | (2,841) | (1,988) |
CASH FLOWS FROM FINANCING ACTIVITIES | ||
Net Change in Commercial Paper and Loans | 20 | (60) |
Issuance of Long-Term Debt | 600 | 1,000 |
Redemption of Long-Term Debt | (300) | (500) |
Redemption of Securitization Debt | (191) | (170) |
Cash Dividends Paid on Common Stock | (592) | (561) |
Other | (55) | (47) |
Net Cash Provided By (Used In) Financing Activities | (518) | (338) |
Net Increase (Decrease) In Cash and Cash Equivalents | (131) | 210 |
Cash and Cash Equivalents at Beginning of Period | 402 | 493 |
Cash and Cash Equivalents at End of Period | 271 | 703 |
Supplemental Disclosure of Cash Flow Information: | ||
Income Taxes Paid (Received) | 292 | 284 |
Interest Paid, Net of Amounts Capitalized | 265 | 269 |
Accrued Property, Plant and Equipment Expenditures | 321 | 286 |
PSE And G [Member] | ||
CASH FLOWS FROM OPERATING ACTIVITIES | ||
Net Income | 631 | 565 |
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities: | ||
Depreciation and Amortization | 712 | 682 |
Provision for Deferred Income Taxes and ITC | 96 | 93 |
Non-Cash Employee Benefit Plan Costs | 71 | 21 |
Change in Accrued Storm Costs | 15 | (3) |
Net Change in Other Regulatory Assets and Liabilities | 26 | 276 |
Cost of Removal | (82) | (68) |
Net Change in Certain Current Assets and Liabilities: | ||
Accounts Receivable and Unbilled Revenues | 30 | 71 |
Fuel, Materials and Supplies | (13) | (15) |
Prepayments | (67) | (92) |
Accounts Payable | 34 | (3) |
Accounts Receivable/Payable-Affiliated Companies, net | 190 | (113) |
Other Current Assets and Liabilities | (18) | (6) |
Employee Benefit Plan Funding and Related Payments | (72) | (67) |
Other | (35) | 2 |
Net Cash Provided By (Used In) Operating Activities | 1,518 | 1,343 |
CASH FLOWS FROM INVESTING ACTIVITIES | ||
Additions to Property, Plant and Equipment | (1,946) | (1,493) |
Proceeds from Sale of Available-for-Sale Securities | 16 | 98 |
Investments in Available-for-Sale Securities | (18) | (96) |
Other | 13 | 1 |
Net Cash Provided By (Used In) Investing Activities | (1,935) | (1,490) |
CASH FLOWS FROM FINANCING ACTIVITIES | ||
Net Change in Short-Term Debt | 20 | (60) |
Issuance of Long-Term Debt | 600 | 1,000 |
Redemption of Long-Term Debt | (300) | (500) |
Redemption of Securitization Debt | (191) | (170) |
Contributed Capital | 0 | 175 |
Other | (8) | (11) |
Net Cash Provided By (Used In) Financing Activities | 121 | 434 |
Net Increase (Decrease) In Cash and Cash Equivalents | (296) | 287 |
Cash and Cash Equivalents at Beginning of Period | 310 | 18 |
Cash and Cash Equivalents at End of Period | 14 | 305 |
Supplemental Disclosure of Cash Flow Information: | ||
Income Taxes Paid (Received) | (29) | 174 |
Interest Paid, Net of Amounts Capitalized | 186 | 188 |
Accrued Property, Plant and Equipment Expenditures | 251 | 238 |
Power [Member] | ||
CASH FLOWS FROM OPERATING ACTIVITIES | ||
Net Income | 707 | 440 |
Adjustments to Reconcile Net Income to Net Cash Flows from Operating Activities: | ||
Depreciation and Amortization | 226 | 215 |
Amortization of Nuclear Fuel | 162 | 151 |
Provision for Deferred Income Taxes and ITC | 109 | 5 |
Non-Cash Employee Benefit Plan Costs | 36 | 10 |
Net Realized and Unrealized (Gains) Losses on Energy Contracts and Other Derivatives | (87) | 237 |
Net Realized (Gains) Losses and (Income) Expense from NDT Fund | (2) | (99) |
Net Change in Certain Current Assets and Liabilities: | ||
Fuel, Materials and Supplies | 113 | 17 |
Margin Deposit | 142 | (173) |
Accounts Receivable | 54 | 49 |
Accounts Payable | (99) | (135) |
Accounts Receivable/Payable-Affiliated Companies, net | 115 | 299 |
Other Current Assets and Liabilities | (26) | 28 |
Employee Benefit Plan Funding and Related Payments | (9) | (5) |
Other | 117 | 71 |
Net Cash Provided By (Used In) Operating Activities | 1,558 | 1,110 |
CASH FLOWS FROM INVESTING ACTIVITIES | ||
Additions to Property, Plant and Equipment | (797) | (414) |
Proceeds from Sale of Available-for-Sale Securities | 1,057 | 882 |
Investments in Available-for-Sale Securities | (1,083) | (898) |
Short-Term Loan-Affiliated Company, net | (281) | 167 |
Other | (46) | (63) |
Net Cash Provided By (Used In) Investing Activities | (1,150) | (326) |
CASH FLOWS FROM FINANCING ACTIVITIES | ||
Cash Dividends Paid on Common Stock | (400) | (775) |
Other | (2) | (3) |
Net Cash Provided By (Used In) Financing Activities | (402) | (778) |
Net Increase (Decrease) In Cash and Cash Equivalents | 6 | 6 |
Cash and Cash Equivalents at Beginning of Period | 9 | 6 |
Cash and Cash Equivalents at End of Period | 15 | 12 |
Supplemental Disclosure of Cash Flow Information: | ||
Income Taxes Paid (Received) | 284 | 87 |
Interest Paid, Net of Amounts Capitalized | 76 | 78 |
Accrued Property, Plant and Equipment Expenditures | $ 70 | $ 66 |
Organization and Basis of Prese
Organization and Basis of Presentation | 9 Months Ended |
Sep. 30, 2015 | |
Organization and Basis of Presentation | Organization and Basis of Presentation Organization PSEG is a holding company with a diversified business mix within the energy industry. Its operations are primarily in the Northeastern and Mid-Atlantic United States and in other select markets. PSEG’s principal direct wholly owned subsidiaries are: • PSE&G —which is an operating public utility engaged principally in the transmission of electricity and distribution of electricity and natural gas in certain areas of New Jersey. PSE&G is subject to regulation by the New Jersey Board of Public Utilities (BPU) and Federal Energy Regulatory Commission (FERC). PSE&G also invests in solar generation projects and has implemented energy efficiency and demand response programs in New Jersey, which are regulated by the BPU. • Power —which is a multi-regional, wholesale energy supply company that integrates its generating asset operations and gas supply commitments with its wholesale energy, fuel supply and energy trading functions through its principal direct wholly owned subsidiaries. Power’s subsidiaries are subject to regulation by FERC, the Nuclear Regulatory Commission (NRC) and the states in which they operate. PSEG's other direct wholly owned subsidiaries include PSEG Energy Holdings L.L.C. (Energy Holdings), which primarily has investments in leveraged leases; PSEG Long Island LLC (PSEG LI), which operates the Long Island Power Authority's (LIPA) transmission and distribution (T&D) system under an Operations Services Agreement (OSA); and PSEG Services Corporation (Services), which provides certain management, administrative and general services to PSEG and its subsidiaries at cost. Basis of Presentation The respective financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC) applicable to Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States (GAAP) have been condensed or omitted pursuant to such rules and regulations. These Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements (Notes) should be read in conjunction with, and update and supplement matters discussed in, the Annual Report on Form 10-K for the year ended December 31, 2014 . The unaudited condensed consolidated financial information furnished herein reflects all adjustments which are, in the opinion of management, necessary to fairly state the results for the interim periods presented. All such adjustments are of a normal recurring nature. All intercompany accounts and transactions are eliminated in consolidation. The year-end Condensed Consolidated Balance Sheets were derived from the audited Consolidated Financial Statements included in the Annual Report on Form 10-K for the year ended December 31, 2014 . |
PSE And G [Member] | |
Organization and Basis of Presentation | Organization and Basis of Presentation Organization PSEG is a holding company with a diversified business mix within the energy industry. Its operations are primarily in the Northeastern and Mid-Atlantic United States and in other select markets. PSEG’s principal direct wholly owned subsidiaries are: • PSE&G —which is an operating public utility engaged principally in the transmission of electricity and distribution of electricity and natural gas in certain areas of New Jersey. PSE&G is subject to regulation by the New Jersey Board of Public Utilities (BPU) and Federal Energy Regulatory Commission (FERC). PSE&G also invests in solar generation projects and has implemented energy efficiency and demand response programs in New Jersey, which are regulated by the BPU. • Power —which is a multi-regional, wholesale energy supply company that integrates its generating asset operations and gas supply commitments with its wholesale energy, fuel supply and energy trading functions through its principal direct wholly owned subsidiaries. Power’s subsidiaries are subject to regulation by FERC, the Nuclear Regulatory Commission (NRC) and the states in which they operate. PSEG's other direct wholly owned subsidiaries include PSEG Energy Holdings L.L.C. (Energy Holdings), which primarily has investments in leveraged leases; PSEG Long Island LLC (PSEG LI), which operates the Long Island Power Authority's (LIPA) transmission and distribution (T&D) system under an Operations Services Agreement (OSA); and PSEG Services Corporation (Services), which provides certain management, administrative and general services to PSEG and its subsidiaries at cost. Basis of Presentation The respective financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC) applicable to Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States (GAAP) have been condensed or omitted pursuant to such rules and regulations. These Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements (Notes) should be read in conjunction with, and update and supplement matters discussed in, the Annual Report on Form 10-K for the year ended December 31, 2014 . The unaudited condensed consolidated financial information furnished herein reflects all adjustments which are, in the opinion of management, necessary to fairly state the results for the interim periods presented. All such adjustments are of a normal recurring nature. All intercompany accounts and transactions are eliminated in consolidation. The year-end Condensed Consolidated Balance Sheets were derived from the audited Consolidated Financial Statements included in the Annual Report on Form 10-K for the year ended December 31, 2014 . |
Power [Member] | |
Organization and Basis of Presentation | Organization and Basis of Presentation Organization PSEG is a holding company with a diversified business mix within the energy industry. Its operations are primarily in the Northeastern and Mid-Atlantic United States and in other select markets. PSEG’s principal direct wholly owned subsidiaries are: • PSE&G —which is an operating public utility engaged principally in the transmission of electricity and distribution of electricity and natural gas in certain areas of New Jersey. PSE&G is subject to regulation by the New Jersey Board of Public Utilities (BPU) and Federal Energy Regulatory Commission (FERC). PSE&G also invests in solar generation projects and has implemented energy efficiency and demand response programs in New Jersey, which are regulated by the BPU. • Power —which is a multi-regional, wholesale energy supply company that integrates its generating asset operations and gas supply commitments with its wholesale energy, fuel supply and energy trading functions through its principal direct wholly owned subsidiaries. Power’s subsidiaries are subject to regulation by FERC, the Nuclear Regulatory Commission (NRC) and the states in which they operate. PSEG's other direct wholly owned subsidiaries include PSEG Energy Holdings L.L.C. (Energy Holdings), which primarily has investments in leveraged leases; PSEG Long Island LLC (PSEG LI), which operates the Long Island Power Authority's (LIPA) transmission and distribution (T&D) system under an Operations Services Agreement (OSA); and PSEG Services Corporation (Services), which provides certain management, administrative and general services to PSEG and its subsidiaries at cost. Basis of Presentation The respective financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC) applicable to Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States (GAAP) have been condensed or omitted pursuant to such rules and regulations. These Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements (Notes) should be read in conjunction with, and update and supplement matters discussed in, the Annual Report on Form 10-K for the year ended December 31, 2014 . The unaudited condensed consolidated financial information furnished herein reflects all adjustments which are, in the opinion of management, necessary to fairly state the results for the interim periods presented. All such adjustments are of a normal recurring nature. All intercompany accounts and transactions are eliminated in consolidation. The year-end Condensed Consolidated Balance Sheets were derived from the audited Consolidated Financial Statements included in the Annual Report on Form 10-K for the year ended December 31, 2014 . |
Recent Accounting Standards
Recent Accounting Standards | 9 Months Ended |
Sep. 30, 2015 | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
Recent Accounting Standards | Recent Accounting Standards New Standards Issued But Not Yet Adopted Revenue from Contracts with Customers This accounting standard was issued to clarify the principles for recognizing revenue and to develop a common standard that would remove inconsistencies in revenue requirements; improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets; and provide improved disclosures. The guidance provides a five-step model to be used for recognizing revenue for the transfer of promised goods and services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The update was originally to be effective for annual and interim reporting periods beginning after December 15, 2016; however, the Financial Accounting Standards Board issued new guidance deferring the effective date by one year to periods beginning after December 31, 2017. Early application will be permitted as of the original effective date. We are currently analyzing the impact of this standard on our financial statements. Amendments to the Consolidation Analysis This standard was issued to respond to concerns regarding the current accounting for consolidation of certain legal entities. Under the new standard, all legal entities are subject to reevaluation under a revised consolidation model which will determine whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities; eliminate the presumption that a general partner should consolidate a limited partnership; affect the consolidation analysis of reporting entities that are involved with VIEs and provide a scope exception from consolidation guidance for reporting entities with interests in certain legal entities who must comply with other requirements. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We are currently analyzing the impact of this standard on our financial statements. Simplifying the Presentation of Debt Issuance Costs This standard was issued to simplify presentation of debt issuance costs. The standard will require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by this standard. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We do not expect the impact of adoption of this standard to be material to our Condensed Consolidated Balance Sheets. |
PSE And G [Member] | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
Recent Accounting Standards | Recent Accounting Standards New Standards Issued But Not Yet Adopted Revenue from Contracts with Customers This accounting standard was issued to clarify the principles for recognizing revenue and to develop a common standard that would remove inconsistencies in revenue requirements; improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets; and provide improved disclosures. The guidance provides a five-step model to be used for recognizing revenue for the transfer of promised goods and services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The update was originally to be effective for annual and interim reporting periods beginning after December 15, 2016; however, the Financial Accounting Standards Board issued new guidance deferring the effective date by one year to periods beginning after December 31, 2017. Early application will be permitted as of the original effective date. We are currently analyzing the impact of this standard on our financial statements. Amendments to the Consolidation Analysis This standard was issued to respond to concerns regarding the current accounting for consolidation of certain legal entities. Under the new standard, all legal entities are subject to reevaluation under a revised consolidation model which will determine whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities; eliminate the presumption that a general partner should consolidate a limited partnership; affect the consolidation analysis of reporting entities that are involved with VIEs and provide a scope exception from consolidation guidance for reporting entities with interests in certain legal entities who must comply with other requirements. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We are currently analyzing the impact of this standard on our financial statements. Simplifying the Presentation of Debt Issuance Costs This standard was issued to simplify presentation of debt issuance costs. The standard will require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by this standard. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We do not expect the impact of adoption of this standard to be material to our Condensed Consolidated Balance Sheets. |
Power [Member] | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
Recent Accounting Standards | Recent Accounting Standards New Standards Issued But Not Yet Adopted Revenue from Contracts with Customers This accounting standard was issued to clarify the principles for recognizing revenue and to develop a common standard that would remove inconsistencies in revenue requirements; improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets; and provide improved disclosures. The guidance provides a five-step model to be used for recognizing revenue for the transfer of promised goods and services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The update was originally to be effective for annual and interim reporting periods beginning after December 15, 2016; however, the Financial Accounting Standards Board issued new guidance deferring the effective date by one year to periods beginning after December 31, 2017. Early application will be permitted as of the original effective date. We are currently analyzing the impact of this standard on our financial statements. Amendments to the Consolidation Analysis This standard was issued to respond to concerns regarding the current accounting for consolidation of certain legal entities. Under the new standard, all legal entities are subject to reevaluation under a revised consolidation model which will determine whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities; eliminate the presumption that a general partner should consolidate a limited partnership; affect the consolidation analysis of reporting entities that are involved with VIEs and provide a scope exception from consolidation guidance for reporting entities with interests in certain legal entities who must comply with other requirements. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We are currently analyzing the impact of this standard on our financial statements. Simplifying the Presentation of Debt Issuance Costs This standard was issued to simplify presentation of debt issuance costs. The standard will require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by this standard. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We do not expect the impact of adoption of this standard to be material to our Condensed Consolidated Balance Sheets. |
Variable Interest Entities (VIE
Variable Interest Entities (VIEs) | 9 Months Ended |
Sep. 30, 2015 | |
Variable Interest Entity [Line Items] | |
Variable Interest Entities (VIEs) | Variable Interest Entities (VIEs) Variable Interest Entities for which PSE&G is the Primary Beneficiary PSE&G is the primary beneficiary and consolidates two marginally capitalized VIEs, PSE&G Transition Funding LLC (Transition Funding) and PSE&G Transition Funding II LLC (Transition Funding II), which were created for the purpose of issuing transition bonds and purchasing bond transitional property of PSE&G, which is pledged as collateral to a trustee. PSE&G acts as the servicer for these entities to collect securitization transition charges authorized by the BPU. These funds are remitted to Transition Funding and Transition Funding II and are used for interest and principal payments on the transition bonds and related costs. The assets and liabilities of Transition Funding and Transition Funding II are presented separately on the face of the Condensed Consolidated Balance Sheets of PSEG and PSE&G because the assets of these VIEs are restricted and can only be used to settle their respective obligations. No Transition Funding or Transition Funding II creditor has any recourse to the general credit of PSE&G in the event the transition charges are not sufficient to cover the bond principal and interest payments of Transition Funding or Transition Funding II. PSE&G’s maximum exposure to loss is equal to its equity investment in these VIEs which was $16 million as of September 30, 2015 and December 31, 2014 . The risk of actual loss to PSE&G is considered remote. PSE&G did not provide any financial support to Transition Funding or Transition Funding II during the first nine months of 2015 or in 2014 . PSE&G does not have any contractual commitments or obligations to provide financial support to Transition Funding or Transition Funding II. In June 2015, Transition Funding II paid its final securitization bond payment and Transition Funding I is scheduled to make its final securitization bond payment in December 2015. Variable Interest Entity for which PSEG LI is the Primary Beneficiary PSEG LI consolidates Long Island Electric Utility Servco, LLC (Servco), a marginally capitalized VIE, which was created for the purpose of operating LIPA's T&D system in Long Island, New York as well as providing administrative support functions to LIPA. PSEG LI is the primary beneficiary of Servco because it directs the operations of Servco, the activity that most significantly impacts Servco's economic performance and it has the obligation to absorb losses of Servco that could potentially be significant to Servco. Such losses would be immaterial to PSEG. Pursuant to the OSA, Servco's operating costs are reimbursable entirely by LIPA, and therefore, PSEG LI's risk is limited related to the activities of Servco. PSEG LI has no current obligation to provide direct financial support to Servco. In addition to reimbursement of Servco’s operating costs as provided for in the OSA, PSEG LI receives an annual contract management fee. PSEG LI’s annual contractual management fee, in certain situations, could be partially offset by Servco's annual storm costs not approved by the Federal Emergency Management Agency, limited contingent liabilities and penalties for failing to meet certain performance metrics. PSEG recognized a long-term receivable primarily related to future funding by LIPA of Servco’s recognized pension and other postretirement benefit (OPEB) liabilities. This receivable is presented separately on the Condensed Consolidated Balance Sheet of PSEG as a noncurrent asset because it is restricted. See Note 7. Pension and Other Postretirement Benefits for additional information. For transactions in which Servco acts as principal, such as transactions with its employees for labor and labor-related activities, including pension and OPEB-related transactions, Servco records revenues and the related pass-through expenditures separately in Operating Revenues and Operation and Maintenance (O&M) Expense, respectively. Servco recorded $96 million and $107 million for the three months and $262 million and $307 million for the nine months ended September 30, 2015 and 2014 , respectively, of O&M costs, the full reimbursement of which was reflected in Operating Revenues. For transactions in which Servco acts as an agent for LIPA, it records revenues and the related expenses on a net basis, resulting in no impact on PSEG's Condensed Consolidated Statement of Operations. |
PSE And G [Member] | |
Variable Interest Entity [Line Items] | |
Variable Interest Entities (VIEs) | Variable Interest Entities (VIEs) Variable Interest Entities for which PSE&G is the Primary Beneficiary PSE&G is the primary beneficiary and consolidates two marginally capitalized VIEs, PSE&G Transition Funding LLC (Transition Funding) and PSE&G Transition Funding II LLC (Transition Funding II), which were created for the purpose of issuing transition bonds and purchasing bond transitional property of PSE&G, which is pledged as collateral to a trustee. PSE&G acts as the servicer for these entities to collect securitization transition charges authorized by the BPU. These funds are remitted to Transition Funding and Transition Funding II and are used for interest and principal payments on the transition bonds and related costs. The assets and liabilities of Transition Funding and Transition Funding II are presented separately on the face of the Condensed Consolidated Balance Sheets of PSEG and PSE&G because the assets of these VIEs are restricted and can only be used to settle their respective obligations. No Transition Funding or Transition Funding II creditor has any recourse to the general credit of PSE&G in the event the transition charges are not sufficient to cover the bond principal and interest payments of Transition Funding or Transition Funding II. PSE&G’s maximum exposure to loss is equal to its equity investment in these VIEs which was $16 million as of September 30, 2015 and December 31, 2014 . The risk of actual loss to PSE&G is considered remote. PSE&G did not provide any financial support to Transition Funding or Transition Funding II during the first nine months of 2015 or in 2014 . PSE&G does not have any contractual commitments or obligations to provide financial support to Transition Funding or Transition Funding II. In June 2015, Transition Funding II paid its final securitization bond payment and Transition Funding I is scheduled to make its final securitization bond payment in December 2015. Variable Interest Entity for which PSEG LI is the Primary Beneficiary PSEG LI consolidates Long Island Electric Utility Servco, LLC (Servco), a marginally capitalized VIE, which was created for the purpose of operating LIPA's T&D system in Long Island, New York as well as providing administrative support functions to LIPA. PSEG LI is the primary beneficiary of Servco because it directs the operations of Servco, the activity that most significantly impacts Servco's economic performance and it has the obligation to absorb losses of Servco that could potentially be significant to Servco. Such losses would be immaterial to PSEG. Pursuant to the OSA, Servco's operating costs are reimbursable entirely by LIPA, and therefore, PSEG LI's risk is limited related to the activities of Servco. PSEG LI has no current obligation to provide direct financial support to Servco. In addition to reimbursement of Servco’s operating costs as provided for in the OSA, PSEG LI receives an annual contract management fee. PSEG LI’s annual contractual management fee, in certain situations, could be partially offset by Servco's annual storm costs not approved by the Federal Emergency Management Agency, limited contingent liabilities and penalties for failing to meet certain performance metrics. PSEG recognized a long-term receivable primarily related to future funding by LIPA of Servco’s recognized pension and other postretirement benefit (OPEB) liabilities. This receivable is presented separately on the Condensed Consolidated Balance Sheet of PSEG as a noncurrent asset because it is restricted. See Note 7. Pension and Other Postretirement Benefits for additional information. For transactions in which Servco acts as principal, such as transactions with its employees for labor and labor-related activities, including pension and OPEB-related transactions, Servco records revenues and the related pass-through expenditures separately in Operating Revenues and Operation and Maintenance (O&M) Expense, respectively. Servco recorded $96 million and $107 million for the three months and $262 million and $307 million for the nine months ended September 30, 2015 and 2014 , respectively, of O&M costs, the full reimbursement of which was reflected in Operating Revenues. For transactions in which Servco acts as an agent for LIPA, it records revenues and the related expenses on a net basis, resulting in no impact on PSEG's Condensed Consolidated Statement of Operations. |
Rate Filings
Rate Filings | 9 Months Ended |
Sep. 30, 2015 | |
Regulatory Assets [Line Items] | |
Rate Filings | Rate Filings The following information discusses significant updates regarding orders and pending rate filings. This Note should be read in conjunction with Note 5. Regulatory Assets and Liabilities to the Consolidated Financial Statements in the Annual Report on Form 10-K for the year ended December 31, 2014 . In addition to items previously reported in the Annual Report on Form 10-K, significant 2015 regulatory orders received and currently pending rate filings with FERC and the BPU by PSE&G are as follows: • Energy Strong Recovery Filing —In June 2015, PSE&G updated its Energy Strong electric and gas cost recovery petition filed in March 2015 seeking BPU approval to recover in base rates estimated annual increases in electric revenues of $6 million and gas revenues of $17 million . These increases represent a return on investment and recovery of Energy Strong capitalized investment costs placed in service from December 1, 2014 through May 31, 2015 for electric and from June 1, 2014 through May 31, 2015 for gas. In August 2015, the BPU provisionally approved PSE&G's request effective September 1, 2015. In September 2015, PSE&G filed its Energy Strong electric cost recovery petition seeking BPU approval to recover the revenue requirements associated with Energy Strong capitalized investment costs placed in service from June 1, 2015 through November 30, 2015. The annualized requested increase in electric revenue requirements is $14 million . The petition requests rates to be effective March 1, 2016, consistent with the BPU Order of approval of the Energy Strong Program. This matter is pending. • Basic Gas Supply Service (BGSS) —In March 2015, PSE&G filed a letter with the BPU to extend the 28 cents per therm residential rate reduction via a bill credit for one additional month through April 30, 2015, which provided an additional approximate $31 million credit to customers. In April 2015, the BPU issued an Order approving PSE&G’s provisional BGSS rate of 45 cents per therm which had been implemented on October 1, 2014. In June 2015, PSE&G made its Annual BGSS Filing with the BPU requesting a reduction of $70 million in annual BGSS revenues. In September 2015, the BPU approved a Stipulation in this matter on a provisional basis and the BGSS rate was reduced from approximately 45 cents to 40 cents per therm effective October 1, 2015. • Weather Normalization Clause —On April 15, 2015, the BPU approved PSE&G's final filing with respect to excess revenues collected during the colder than normal 2013-2014 Winter Period (October 1, 2013 through May 31, 2014). Effective October 1, 2014, PSEG commenced returning $45 million in revenues to its customers during the 2014-2015 Winter Period (October 1, 2014 through May 31, 2015). In September 2015, the BPU approved PSE&G's filing on a provisional basis with respect to excess revenues collected during the colder than normal 2014-2015 Winter Period. Effective October 1, 2015, PSE&G commenced returning $40 million in revenues to its customers during the 2015-2016 Winter Period (October 1, 2015 through May 31, 2016). • Solar and Energy Efficiency - Green Program Recovery Charges (GPRC) and Solar Pilot Recovery Charge (SPRC) —In April 2015, the BPU approved PSE&G’s petition for an Energy Efficiency Economic Stimulus Extension II Program (EEE Ext II) to extend three EEE subprograms (multi-family, direct install and hospital efficiency). The Order allows PSE&G to extend the subprogram offerings under the same clause recovery process as its existing EEE Program and allows for $95 million of additional capital expenditures over the next three years and an allowance for $12 million of additional administrative expenses over the next 15 years. The EEE Ext II program was added as a ninth component of the GPRC rate effective May 1, 2015. In July of each year, PSE&G files for annual recovery for its Green Program investments which include a return on its investment and recovery of expenses. In May 2015, the BPU approved PSE&G’s July 2014 filing requesting recovery of costs and investments in the first eight combined components of the electric and gas GPRC for the period October 1, 2014 through September 30, 2015. In July 2015, PSE&G filed its annual GPRC and SPRC cost recovery petitions with the BPU, requesting recovery of costs and investments for the first eight combined components of the electric and gas GPRC, as well as the electric SPRC. The filings proposed rates for the period October 1, 2015 through September 30, 2016 designed to recover approximately $66 million and $10 million in electric and gas revenues, respectively, on an annual basis associated with PSE&G's implementation of these BPU approved programs. In September 2015, the BPU approved the July 2015 filings on a provisional basis, with new rates effective October 1, 2015. • Transmission Formula Rate Filings —In June 2015, PSE&G filed its 2014 true-up adjustment pertaining to its formula rates in effect for 2014, which resulted in an adjustment of $19 million less than the 2014 filed revenues. The adjustment was primarily due to the impact of bonus depreciation and lower interest rates which PSE&G had recognized in its Consolidated Statement of Operations for the year ended December 31, 2014. The 2016 Annual Formula Rate Update was filed with FERC in October 2015 and provides for approximately $146 million in increased annual transmission revenues effective January 1, 2016. • Remediation Adjustment Charge (RAC) —In August 2015, the BPU approved PSE&G's filing with respect to its RAC 22 petition allowing recovery of $85 million effective September 1, 2015 related to net Manufactured Gas Plant expenditures from August 1, 2013 through July 31, 2014. • Universal Service Fund (USF)/Lifeline —In September 2015, the BPU approved rates set to recover costs incurred under the USF/Lifeline energy assistance programs effective October 1, 2015. PSE&G earns no margin on the collection of the USF and Lifeline programs resulting in no impact on Net Income. |
PSE And G [Member] | |
Regulatory Assets [Line Items] | |
Rate Filings | Rate Filings The following information discusses significant updates regarding orders and pending rate filings. This Note should be read in conjunction with Note 5. Regulatory Assets and Liabilities to the Consolidated Financial Statements in the Annual Report on Form 10-K for the year ended December 31, 2014 . In addition to items previously reported in the Annual Report on Form 10-K, significant 2015 regulatory orders received and currently pending rate filings with FERC and the BPU by PSE&G are as follows: • Energy Strong Recovery Filing —In June 2015, PSE&G updated its Energy Strong electric and gas cost recovery petition filed in March 2015 seeking BPU approval to recover in base rates estimated annual increases in electric revenues of $6 million and gas revenues of $17 million . These increases represent a return on investment and recovery of Energy Strong capitalized investment costs placed in service from December 1, 2014 through May 31, 2015 for electric and from June 1, 2014 through May 31, 2015 for gas. In August 2015, the BPU provisionally approved PSE&G's request effective September 1, 2015. In September 2015, PSE&G filed its Energy Strong electric cost recovery petition seeking BPU approval to recover the revenue requirements associated with Energy Strong capitalized investment costs placed in service from June 1, 2015 through November 30, 2015. The annualized requested increase in electric revenue requirements is $14 million . The petition requests rates to be effective March 1, 2016, consistent with the BPU Order of approval of the Energy Strong Program. This matter is pending. • Basic Gas Supply Service (BGSS) —In March 2015, PSE&G filed a letter with the BPU to extend the 28 cents per therm residential rate reduction via a bill credit for one additional month through April 30, 2015, which provided an additional approximate $31 million credit to customers. In April 2015, the BPU issued an Order approving PSE&G’s provisional BGSS rate of 45 cents per therm which had been implemented on October 1, 2014. In June 2015, PSE&G made its Annual BGSS Filing with the BPU requesting a reduction of $70 million in annual BGSS revenues. In September 2015, the BPU approved a Stipulation in this matter on a provisional basis and the BGSS rate was reduced from approximately 45 cents to 40 cents per therm effective October 1, 2015. • Weather Normalization Clause —On April 15, 2015, the BPU approved PSE&G's final filing with respect to excess revenues collected during the colder than normal 2013-2014 Winter Period (October 1, 2013 through May 31, 2014). Effective October 1, 2014, PSEG commenced returning $45 million in revenues to its customers during the 2014-2015 Winter Period (October 1, 2014 through May 31, 2015). In September 2015, the BPU approved PSE&G's filing on a provisional basis with respect to excess revenues collected during the colder than normal 2014-2015 Winter Period. Effective October 1, 2015, PSE&G commenced returning $40 million in revenues to its customers during the 2015-2016 Winter Period (October 1, 2015 through May 31, 2016). • Solar and Energy Efficiency - Green Program Recovery Charges (GPRC) and Solar Pilot Recovery Charge (SPRC) —In April 2015, the BPU approved PSE&G’s petition for an Energy Efficiency Economic Stimulus Extension II Program (EEE Ext II) to extend three EEE subprograms (multi-family, direct install and hospital efficiency). The Order allows PSE&G to extend the subprogram offerings under the same clause recovery process as its existing EEE Program and allows for $95 million of additional capital expenditures over the next three years and an allowance for $12 million of additional administrative expenses over the next 15 years. The EEE Ext II program was added as a ninth component of the GPRC rate effective May 1, 2015. In July of each year, PSE&G files for annual recovery for its Green Program investments which include a return on its investment and recovery of expenses. In May 2015, the BPU approved PSE&G’s July 2014 filing requesting recovery of costs and investments in the first eight combined components of the electric and gas GPRC for the period October 1, 2014 through September 30, 2015. In July 2015, PSE&G filed its annual GPRC and SPRC cost recovery petitions with the BPU, requesting recovery of costs and investments for the first eight combined components of the electric and gas GPRC, as well as the electric SPRC. The filings proposed rates for the period October 1, 2015 through September 30, 2016 designed to recover approximately $66 million and $10 million in electric and gas revenues, respectively, on an annual basis associated with PSE&G's implementation of these BPU approved programs. In September 2015, the BPU approved the July 2015 filings on a provisional basis, with new rates effective October 1, 2015. • Transmission Formula Rate Filings —In June 2015, PSE&G filed its 2014 true-up adjustment pertaining to its formula rates in effect for 2014, which resulted in an adjustment of $19 million less than the 2014 filed revenues. The adjustment was primarily due to the impact of bonus depreciation and lower interest rates which PSE&G had recognized in its Consolidated Statement of Operations for the year ended December 31, 2014. The 2016 Annual Formula Rate Update was filed with FERC in October 2015 and provides for approximately $146 million in increased annual transmission revenues effective January 1, 2016. • Remediation Adjustment Charge (RAC) —In August 2015, the BPU approved PSE&G's filing with respect to its RAC 22 petition allowing recovery of $85 million effective September 1, 2015 related to net Manufactured Gas Plant expenditures from August 1, 2013 through July 31, 2014. • Universal Service Fund (USF)/Lifeline —In September 2015, the BPU approved rates set to recover costs incurred under the USF/Lifeline energy assistance programs effective October 1, 2015. PSE&G earns no margin on the collection of the USF and Lifeline programs resulting in no impact on Net Income. |
Financing Receivables
Financing Receivables | 9 Months Ended |
Sep. 30, 2015 | |
Schedule of Financial Receivables [Line Items] | |
Financing Receivables | Financing Receivables PSE&G PSE&G sponsors a solar loan program designed to help finance the installation of solar power systems throughout its electric service area. The loans are generally paid back with Solar Renewable Energy Certificates generated from the installed solar electric system. A substantial portion of these amounts are noncurrent and reported in Long-Term Investments on PSEG's and PSE&G's Condensed Consolidated Balance Sheets. The following table reflects the outstanding loans by class of customer, none of which are considered “non-performing.” Credit Risk Profile Based on Payment Activity As of As of Consumer Loans September 30, December 31, Millions Commercial/Industrial $ 180 $ 188 Residential 13 13 Total $ 193 $ 201 Energy Holdings Energy Holdings, through several of its indirect subsidiary companies, has investments in domestic energy and real estate assets subject primarily to leveraged lease accounting. A leveraged lease is typically comprised of an investment by an equity investor and debt provided by a third party debt investor. The debt is recourse only to the assets subject to lease and is not included on PSEG’s Condensed Consolidated Balance Sheets. As an equity investor, Energy Holdings’ investments in the leases are comprised of the total expected lease receivables on its investments over the lease terms plus the estimated residual values at the end of the lease terms, reduced for any income not yet earned on the leases. This amount is included in Long-Term Investments on PSEG’s Condensed Consolidated Balance Sheets. The more rapid depreciation of the leased property for tax purposes creates tax cash flow that will be repaid to the taxing authority in later periods. As such, the liability for such taxes due is recorded in Deferred Income Taxes on PSEG’s Condensed Consolidated Balance Sheets. The following table shows Energy Holdings’ gross and net lease investment as of September 30, 2015 and December 31, 2014 , respectively. As of As of September 30, December 31, Millions Lease Receivables (net of Non-Recourse Debt) $ 631 $ 691 Estimated Residual Value of Leased Assets 519 525 Unearned and Deferred Income (368 ) (380 ) Gross Investment in Leases 782 836 Deferred Tax Liabilities (706 ) (738 ) Net Investment in Leases $ 76 $ 98 The corresponding receivables associated with the lease portfolio are reflected in the following table, net of non-recourse debt. The ratings in the table represent the ratings of the entities providing payment assurance to Energy Holdings. Lease Receivables, Net of Non-Recourse Debt Counterparties’ Credit Rating (Standard & Poor's (S&P)) As of As of September 30, 2015 September 30, 2015 Millions AA $ 17 BBB+ — BBB- 316 BB- 134 B- 164 Total $ 631 The “ BB- ” and the " B- " ratings in the preceding table represent lease receivables related to coal-fired assets in Illinois and Pennsylvania, respectively. As of September 30, 2015 , the gross investment in the leases of such assets, net of non-recourse debt, was $573 million ( $(13) million , net of deferred taxes). A more detailed description of such assets under lease, as of September 30, 2015 , is presented in the following table. Asset Location Gross Investment % Owned Total Fuel Type Counter-parties’ S&P Credit Ratings As of September 30, 2015 (A) Counterparty Millions MW Powerton Station Units 5 and 6 IL $ 134 64 % 1,538 Coal BB- NRG Energy, Inc. Joliet Station Units 7 and 8 IL $ 84 64 % 1,044 Coal BB- NRG Energy, Inc. Keystone Station Units 1 and 2 PA $ 121 17 % 1,711 Coal B- NRG REMA, LLC Conemaugh Station Units 1 and 2 PA $ 121 17 % 1,711 Coal B- NRG REMA, LLC Shawville Station Units 1, 2, 3 and 4 PA $ 113 100 % 603 Coal B- NRG REMA, LLC (A) On October 2, 2015, S&P lowered the B- rating for NRG REMA, LLC, an indirect subsidiary of NRG Energy, Inc., to CCC+. Potential adverse consequences relevant to the downgrade are discussed in the following paragraph. The credit exposure for lessors is partially mitigated through various credit enhancement mechanisms within the lease transactions. These credit enhancement features vary from lease to lease and may include letters of credit or affiliate guarantees. Upon the occurrence of certain defaults, indirect subsidiary companies of Energy Holdings would exercise their rights and attempt to seek recovery of their investment, potentially including stepping into the lease directly to protect their investments. While these actions could ultimately protect or mitigate the loss of value, they could require the use of significant capital investments and trigger certain material tax obligations. A bankruptcy of a lessee would likely delay any efforts on the part of the lessors to assert their rights upon default and could delay the monetization of claims. Failure to recover adequate value could ultimately lead to a foreclosure on the assets under lease by the lenders. If foreclosures were to occur, Energy Holdings could potentially record a pre-tax write-off up to its gross investment in these facilities and may also be required to pay significant cash tax liabilities to the Internal Revenue Service (IRS). Although all lease payments are current, no assurances can be given that future payments in accordance with the lease contracts will continue. Factors which may impact future lease cash flows include, but are not limited to, new environmental legislation and regulation regarding air quality, water and other discharges in the process of generating electricity, market prices for fuel, electricity and capacity, overall financial condition of lease counterparties and the quality and condition of assets under lease. In early 2014, NRG REMA, LLC had disclosed its plan to place the Shawville generating facility in a “long-term protective layup” by April 2015 as it evaluated its alternatives under the lease. However, NRG has since notified PJM that it deactivated the coal-fired units at the Shawville generating facility in June 2015 and has disclosed that it expects to return the Shawville units to service in the summer of 2016 with the ability to use natural gas. |
PSE And G [Member] | |
Schedule of Financial Receivables [Line Items] | |
Financing Receivables | Financing Receivables PSE&G PSE&G sponsors a solar loan program designed to help finance the installation of solar power systems throughout its electric service area. The loans are generally paid back with Solar Renewable Energy Certificates generated from the installed solar electric system. A substantial portion of these amounts are noncurrent and reported in Long-Term Investments on PSEG's and PSE&G's Condensed Consolidated Balance Sheets. The following table reflects the outstanding loans by class of customer, none of which are considered “non-performing.” Credit Risk Profile Based on Payment Activity As of As of Consumer Loans September 30, December 31, Millions Commercial/Industrial $ 180 $ 188 Residential 13 13 Total $ 193 $ 201 Energy Holdings Energy Holdings, through several of its indirect subsidiary companies, has investments in domestic energy and real estate assets subject primarily to leveraged lease accounting. A leveraged lease is typically comprised of an investment by an equity investor and debt provided by a third party debt investor. The debt is recourse only to the assets subject to lease and is not included on PSEG’s Condensed Consolidated Balance Sheets. As an equity investor, Energy Holdings’ investments in the leases are comprised of the total expected lease receivables on its investments over the lease terms plus the estimated residual values at the end of the lease terms, reduced for any income not yet earned on the leases. This amount is included in Long-Term Investments on PSEG’s Condensed Consolidated Balance Sheets. The more rapid depreciation of the leased property for tax purposes creates tax cash flow that will be repaid to the taxing authority in later periods. As such, the liability for such taxes due is recorded in Deferred Income Taxes on PSEG’s Condensed Consolidated Balance Sheets. The following table shows Energy Holdings’ gross and net lease investment as of September 30, 2015 and December 31, 2014 , respectively. As of As of September 30, December 31, Millions Lease Receivables (net of Non-Recourse Debt) $ 631 $ 691 Estimated Residual Value of Leased Assets 519 525 Unearned and Deferred Income (368 ) (380 ) Gross Investment in Leases 782 836 Deferred Tax Liabilities (706 ) (738 ) Net Investment in Leases $ 76 $ 98 The corresponding receivables associated with the lease portfolio are reflected in the following table, net of non-recourse debt. The ratings in the table represent the ratings of the entities providing payment assurance to Energy Holdings. Lease Receivables, Net of Non-Recourse Debt Counterparties’ Credit Rating (Standard & Poor's (S&P)) As of As of September 30, 2015 September 30, 2015 Millions AA $ 17 BBB+ — BBB- 316 BB- 134 B- 164 Total $ 631 The “ BB- ” and the " B- " ratings in the preceding table represent lease receivables related to coal-fired assets in Illinois and Pennsylvania, respectively. As of September 30, 2015 , the gross investment in the leases of such assets, net of non-recourse debt, was $573 million ( $(13) million , net of deferred taxes). A more detailed description of such assets under lease, as of September 30, 2015 , is presented in the following table. Asset Location Gross Investment % Owned Total Fuel Type Counter-parties’ S&P Credit Ratings As of September 30, 2015 (A) Counterparty Millions MW Powerton Station Units 5 and 6 IL $ 134 64 % 1,538 Coal BB- NRG Energy, Inc. Joliet Station Units 7 and 8 IL $ 84 64 % 1,044 Coal BB- NRG Energy, Inc. Keystone Station Units 1 and 2 PA $ 121 17 % 1,711 Coal B- NRG REMA, LLC Conemaugh Station Units 1 and 2 PA $ 121 17 % 1,711 Coal B- NRG REMA, LLC Shawville Station Units 1, 2, 3 and 4 PA $ 113 100 % 603 Coal B- NRG REMA, LLC (A) On October 2, 2015, S&P lowered the B- rating for NRG REMA, LLC, an indirect subsidiary of NRG Energy, Inc., to CCC+. Potential adverse consequences relevant to the downgrade are discussed in the following paragraph. The credit exposure for lessors is partially mitigated through various credit enhancement mechanisms within the lease transactions. These credit enhancement features vary from lease to lease and may include letters of credit or affiliate guarantees. Upon the occurrence of certain defaults, indirect subsidiary companies of Energy Holdings would exercise their rights and attempt to seek recovery of their investment, potentially including stepping into the lease directly to protect their investments. While these actions could ultimately protect or mitigate the loss of value, they could require the use of significant capital investments and trigger certain material tax obligations. A bankruptcy of a lessee would likely delay any efforts on the part of the lessors to assert their rights upon default and could delay the monetization of claims. Failure to recover adequate value could ultimately lead to a foreclosure on the assets under lease by the lenders. If foreclosures were to occur, Energy Holdings could potentially record a pre-tax write-off up to its gross investment in these facilities and may also be required to pay significant cash tax liabilities to the Internal Revenue Service (IRS). Although all lease payments are current, no assurances can be given that future payments in accordance with the lease contracts will continue. Factors which may impact future lease cash flows include, but are not limited to, new environmental legislation and regulation regarding air quality, water and other discharges in the process of generating electricity, market prices for fuel, electricity and capacity, overall financial condition of lease counterparties and the quality and condition of assets under lease. In early 2014, NRG REMA, LLC had disclosed its plan to place the Shawville generating facility in a “long-term protective layup” by April 2015 as it evaluated its alternatives under the lease. However, NRG has since notified PJM that it deactivated the coal-fired units at the Shawville generating facility in June 2015 and has disclosed that it expects to return the Shawville units to service in the summer of 2016 with the ability to use natural gas. |
Available-for-Sale Securities
Available-for-Sale Securities | 9 Months Ended |
Sep. 30, 2015 | |
Schedule of Available-for-sale Securities [Line Items] | |
Available-for-Sale Securities | Available-for-Sale Securities Nuclear Decommissioning Trust (NDT) Fund Power maintains an external master nuclear decommissioning trust to fund its share of decommissioning for its five nuclear facilities upon termination of operation. The trust contains a qualified fund and a non-qualified fund. Section 468A of the Internal Revenue Code limits the amount of money that can be contributed into a qualified fund. The trust funds are managed by third party investment advisers who operate under investment guidelines developed by Power. Power classifies investments in the NDT Fund as available-for-sale. The following tables show the fair values and gross unrealized gains and losses for the securities held in the NDT Fund. As of September 30, 2015 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 667 $ 176 $ (18 ) $ 825 Debt Securities Government Obligations 445 10 (1 ) 454 Other Debt Securities 402 6 (7 ) 401 Total Debt Securities 847 16 (8 ) 855 Other Securities 35 — — 35 Total NDT Available-for-Sale Securities $ 1,549 $ 192 $ (26 ) $ 1,715 As of December 31, 2014 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 685 $ 220 $ (8 ) $ 897 Debt Securities Government Obligations 430 9 (1 ) 438 Other Debt Securities 333 9 (3 ) 339 Total Debt Securities 763 18 (4 ) 777 Other Securities 106 — — 106 Total NDT Available-for-Sale Securities $ 1,554 $ 238 $ (12 ) $ 1,780 The amounts in the preceding tables do not include receivables and payables for NDT Fund transactions which have not settled at the end of each period. Such amounts are included in Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets as shown in the following table. As of As of September 30, December 31, Millions Accounts Receivable $ 10 $ 10 Accounts Payable $ 4 $ 2 The following table shows the value of securities in the NDT Fund that have been in an unrealized loss position for less than and greater than 12 months. As of September 30, 2015 As of December 31, 2014 Less Than 12 Months Greater Than 12 Months Less Than 12 Months Greater Than 12 Months Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Millions Equity Securities (A) $ 143 $ (18 ) $ 1 $ — $ 162 $ (8 ) $ 1 $ — Debt Securities Government Obligations (B) 90 (1 ) 15 — 95 — 28 (1 ) Other Debt Securities (C) 164 (5 ) 29 (2 ) 99 (1 ) 30 (2 ) Total Debt Securities 254 (6 ) 44 (2 ) 194 (1 ) 58 (3 ) NDT Available-for-Sale Securities $ 397 $ (24 ) $ 45 $ (2 ) $ 356 $ (9 ) $ 59 $ (3 ) (A) Equity Securities—Investments in marketable equity securities within the NDT Fund are primarily in common stocks within a broad range of industries and sectors. The unrealized losses are distributed over a broad range of securities with limited impairment durations. Power does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (B) Debt Securities (Government)—Unrealized losses on Power’s NDT investments in United States Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. Since these investments are guaranteed by the United States government or an agency of the United States government, it is not expected that these securities will settle for less than their amortized cost basis, since Power does not intend to sell nor will it be more-likely-than-not required to sell. Power does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (C) Debt Securities (Other)—Power’s investments in corporate bonds, collateralized mortgage obligations, asset-backed securities and municipal government obligations are limited to investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since Power does not intend to sell these securities nor will it be more-likely-than-not required to sell, Power does not consider these debt securities to be other-than-temporarily impaired as of September 30, 2015 . The proceeds from the sales of and the net realized gains on securities in the NDT Fund were: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions Proceeds from NDT Fund Sales (A) $ 215 $ 221 $ 1,037 $ 779 Net Realized Gains (Losses) on NDT Fund: Gross Realized Gains 14 45 47 101 Gross Realized Losses (11 ) (3 ) (24 ) (12 ) Net Realized Gains (Losses) on NDT Fund $ 3 $ 42 $ 23 $ 89 (A) Includes activity in accounts related to the liquidation of funds being transitioned to new managers. Gross realized gains and gross realized losses disclosed in the preceding table were recognized in Other Income and Other Deductions, respectively, in PSEG’s and Power’s Condensed Consolidated Statements of Operations. Net unrealized gains of $82 million (after-tax) were a component of Accumulated Other Comprehensive Loss on PSEG's and Power’s Condensed Consolidated Balance Sheets as of September 30, 2015 . The NDT available-for-sale debt securities held as of September 30, 2015 had the following maturities: Time Frame Fair Value Millions Less than one year $ 8 1 - 5 years 236 6 - 10 years 201 11 - 15 years 51 16 - 20 years 51 Over 20 years 308 Total NDT Available-for-Sale Debt Securities $ 855 The cost of these securities was determined on the basis of specific identification. Power periodically assesses individual securities whose fair value is less than amortized cost to determine whether the investments are considered to be other-than-temporarily impaired. For equity securities, management considers the ability and intent to hold for a reasonable time to permit recovery in addition to the severity and duration of the loss. For fixed income securities, management considers its intent to sell or requirement to sell a security prior to expected recovery. In those cases where a sale is expected, any impairment would be recorded through earnings. For fixed income securities where there is no intent to sell or likely requirement to sell, management evaluates whether credit loss is a component of the impairment. If so, that portion is recorded through earnings while the noncredit loss component is recorded through Accumulated Other Comprehensive Income (Loss). For the nine months ended September 30, 2015 , other-than-temporary impairments of $45 million were recognized on securities in the NDT Fund. Any subsequent recoveries in the value of these securities would be recognized in Accumulated Other Comprehensive Income (Loss) unless the securities are sold, in which case, any gain would be recognized in income. The assessment of fair market value compared to cost is applied on a weighted average basis taking into account various purchase dates and initial cost of the securities. Rabbi Trust PSEG maintains certain unfunded nonqualified benefit plans to provide supplemental retirement and deferred compensation benefits to certain key employees. Certain assets related to these plans have been set aside in a grantor trust commonly known as a “Rabbi Trust.” PSEG classifies investments in the Rabbi Trust as available-for-sale. The following tables show the fair values, gross unrealized gains and losses and amortized cost basis for the securities held in the Rabbi Trust. As of September 30, 2015 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 11 $ 9 $ — $ 20 Debt Securities Government Obligations 106 1 (1 ) 106 Other Debt Securities 86 — (2 ) 84 Total Debt Securities 192 1 (3 ) 190 Other Securities 1 — — 1 Total Rabbi Trust Available-for-Sale Securities $ 204 $ 10 $ (3 ) $ 211 As of December 31, 2014 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 12 $ 11 $ — $ 23 Debt Securities Government Obligations 89 2 — 91 Other Debt Securities 74 1 — 75 Total Debt Securities 163 3 — 166 Other Securities 2 — — 2 Total Rabbi Trust Available-for-Sale Securities $ 177 $ 14 $ — $ 191 The amounts in the preceding tables do not include receivables and payables for Rabbi Trust Fund transactions which have not settled at the end of each period. Such amounts are included in Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets as shown in the following table. As of As of September 30, December 31, Millions Accounts Receivable $ 1 $ 1 Accounts Payable $ 1 $ — The following table shows the value of securities in the Rabbi Trust Fund that have been in an unrealized loss position for less than and greater than 12 months. As of September 30, 2015 As of December 31, 2014 Less Than 12 Months Greater Than 12 Months Less Than 12 Months Greater Than 12 Months Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Millions Equity Securities (A) $ — $ — $ — $ — $ — $ — $ — $ — Debt Securities Government Obligations (B) 47 (2 ) 2 — 2 — — — Other Debt Securities (C) 41 (1 ) 9 — 24 — — — Total Debt Securities 88 (3 ) 11 — 26 — — — Rabbi Trust Available-for-Sale Securities $ 88 $ (3 ) $ 11 $ — $ 26 $ — $ — $ — (A) Equity Securities—Investments in marketable equity securities within the Rabbi Trust Fund are through a mutual fund which invests primarily in common stocks within a broad range of industries and sectors. (B) Debt Securities (Government)—Unrealized losses on PSEG’s Rabbi Trust investments in United States Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. Since these investments are guaranteed by the United States government or an agency of the United States government, it is not expected that these securities will settle for less than their amortized cost basis, since PSEG does not intend to sell nor will it be more-likely-than-not required to sell. PSEG does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (C) Debt Securities (Other)—PSEG’s investments in corporate bonds, collateralized mortgage obligations, asset-backed securities and municipal government obligations are limited to investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since PSEG does not intend to sell these securities nor will it be more-likely-than-not required to sell, PSEG does not consider these debt securities to be other-than-temporarily impaired as of September 30, 2015 . The proceeds from the sales of and the net realized gains (losses) on securities in the Rabbi Trust Fund were: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions Proceeds from Rabbi Trust Sales (A) $ 20 $ 419 $ 83 $ 445 Net Realized Gains (Losses) on Rabbi Trust: Gross Realized Gains $ — $ 2 $ 2 $ 4 Gross Realized Losses (1 ) (2 ) (1 ) (3 ) Net Realized Gains (Losses) on Rabbi Trust $ (1 ) $ — $ 1 $ 1 (A) Includes activity in accounts related to the liquidation of funds being transitioned to new managers. Gross realized gains disclosed in the preceding table were recognized in Other Income in the Condensed Consolidated Statements of Operations. Net unrealized gains of $4 million (after-tax) were a component of Accumulated Other Comprehensive Loss on the Condensed Consolidated Balance Sheets as of September 30, 2015 . The Rabbi Trust available-for-sale debt securities held as of September 30, 2015 had the following maturities: Time Frame Fair Value Millions Less than one year $ 5 1 - 5 years 49 6 - 10 years 39 11 - 15 years 8 16 - 20 years 9 Over 20 years 80 Total Rabbi Trust Available-for-Sale Debt Securities $ 190 The cost of these securities was determined on the basis of specific identification. PSEG periodically assesses individual securities whose fair value is less than amortized cost to determine whether the investments are considered to be other-than-temporarily impaired. For equity securities, the Rabbi Trust is invested in a commingled indexed mutual fund. Due to the commingled nature of this fund, PSEG does not have the ability to hold these securities until expected recovery. As a result, any declines in fair market value below cost are recorded as a charge to earnings. For fixed income securities, management considers its intent to sell or requirement to sell a security prior to expected recovery. In those cases where a sale is expected, any impairment would be recorded through earnings. For fixed income securities where there is no intent to sell or likely requirement to sell, management evaluates whether credit loss is a component of the impairment. If so, that portion is recorded through earnings while the noncredit loss component is recorded through Accumulated Other Comprehensive Income (Loss). The assessment of fair market value compared to cost is applied on a weighted average basis taking into account various purchase dates and initial cost of the securities. The fair value of assets in the Rabbi Trust related to PSEG, PSE&G and Power are detailed as follows: As of As of September 30, December 31, Millions PSE&G $ 42 $ 41 Power 52 45 Other 117 105 Total Rabbi Trust Available-for-Sale Securities $ 211 $ 191 |
PSE And G [Member] | |
Schedule of Available-for-sale Securities [Line Items] | |
Available-for-Sale Securities | Available-for-Sale Securities Nuclear Decommissioning Trust (NDT) Fund Power maintains an external master nuclear decommissioning trust to fund its share of decommissioning for its five nuclear facilities upon termination of operation. The trust contains a qualified fund and a non-qualified fund. Section 468A of the Internal Revenue Code limits the amount of money that can be contributed into a qualified fund. The trust funds are managed by third party investment advisers who operate under investment guidelines developed by Power. Power classifies investments in the NDT Fund as available-for-sale. The following tables show the fair values and gross unrealized gains and losses for the securities held in the NDT Fund. As of September 30, 2015 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 667 $ 176 $ (18 ) $ 825 Debt Securities Government Obligations 445 10 (1 ) 454 Other Debt Securities 402 6 (7 ) 401 Total Debt Securities 847 16 (8 ) 855 Other Securities 35 — — 35 Total NDT Available-for-Sale Securities $ 1,549 $ 192 $ (26 ) $ 1,715 As of December 31, 2014 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 685 $ 220 $ (8 ) $ 897 Debt Securities Government Obligations 430 9 (1 ) 438 Other Debt Securities 333 9 (3 ) 339 Total Debt Securities 763 18 (4 ) 777 Other Securities 106 — — 106 Total NDT Available-for-Sale Securities $ 1,554 $ 238 $ (12 ) $ 1,780 The amounts in the preceding tables do not include receivables and payables for NDT Fund transactions which have not settled at the end of each period. Such amounts are included in Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets as shown in the following table. As of As of September 30, December 31, Millions Accounts Receivable $ 10 $ 10 Accounts Payable $ 4 $ 2 The following table shows the value of securities in the NDT Fund that have been in an unrealized loss position for less than and greater than 12 months. As of September 30, 2015 As of December 31, 2014 Less Than 12 Months Greater Than 12 Months Less Than 12 Months Greater Than 12 Months Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Millions Equity Securities (A) $ 143 $ (18 ) $ 1 $ — $ 162 $ (8 ) $ 1 $ — Debt Securities Government Obligations (B) 90 (1 ) 15 — 95 — 28 (1 ) Other Debt Securities (C) 164 (5 ) 29 (2 ) 99 (1 ) 30 (2 ) Total Debt Securities 254 (6 ) 44 (2 ) 194 (1 ) 58 (3 ) NDT Available-for-Sale Securities $ 397 $ (24 ) $ 45 $ (2 ) $ 356 $ (9 ) $ 59 $ (3 ) (A) Equity Securities—Investments in marketable equity securities within the NDT Fund are primarily in common stocks within a broad range of industries and sectors. The unrealized losses are distributed over a broad range of securities with limited impairment durations. Power does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (B) Debt Securities (Government)—Unrealized losses on Power’s NDT investments in United States Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. Since these investments are guaranteed by the United States government or an agency of the United States government, it is not expected that these securities will settle for less than their amortized cost basis, since Power does not intend to sell nor will it be more-likely-than-not required to sell. Power does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (C) Debt Securities (Other)—Power’s investments in corporate bonds, collateralized mortgage obligations, asset-backed securities and municipal government obligations are limited to investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since Power does not intend to sell these securities nor will it be more-likely-than-not required to sell, Power does not consider these debt securities to be other-than-temporarily impaired as of September 30, 2015 . The proceeds from the sales of and the net realized gains on securities in the NDT Fund were: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions Proceeds from NDT Fund Sales (A) $ 215 $ 221 $ 1,037 $ 779 Net Realized Gains (Losses) on NDT Fund: Gross Realized Gains 14 45 47 101 Gross Realized Losses (11 ) (3 ) (24 ) (12 ) Net Realized Gains (Losses) on NDT Fund $ 3 $ 42 $ 23 $ 89 (A) Includes activity in accounts related to the liquidation of funds being transitioned to new managers. Gross realized gains and gross realized losses disclosed in the preceding table were recognized in Other Income and Other Deductions, respectively, in PSEG’s and Power’s Condensed Consolidated Statements of Operations. Net unrealized gains of $82 million (after-tax) were a component of Accumulated Other Comprehensive Loss on PSEG's and Power’s Condensed Consolidated Balance Sheets as of September 30, 2015 . The NDT available-for-sale debt securities held as of September 30, 2015 had the following maturities: Time Frame Fair Value Millions Less than one year $ 8 1 - 5 years 236 6 - 10 years 201 11 - 15 years 51 16 - 20 years 51 Over 20 years 308 Total NDT Available-for-Sale Debt Securities $ 855 The cost of these securities was determined on the basis of specific identification. Power periodically assesses individual securities whose fair value is less than amortized cost to determine whether the investments are considered to be other-than-temporarily impaired. For equity securities, management considers the ability and intent to hold for a reasonable time to permit recovery in addition to the severity and duration of the loss. For fixed income securities, management considers its intent to sell or requirement to sell a security prior to expected recovery. In those cases where a sale is expected, any impairment would be recorded through earnings. For fixed income securities where there is no intent to sell or likely requirement to sell, management evaluates whether credit loss is a component of the impairment. If so, that portion is recorded through earnings while the noncredit loss component is recorded through Accumulated Other Comprehensive Income (Loss). For the nine months ended September 30, 2015 , other-than-temporary impairments of $45 million were recognized on securities in the NDT Fund. Any subsequent recoveries in the value of these securities would be recognized in Accumulated Other Comprehensive Income (Loss) unless the securities are sold, in which case, any gain would be recognized in income. The assessment of fair market value compared to cost is applied on a weighted average basis taking into account various purchase dates and initial cost of the securities. Rabbi Trust PSEG maintains certain unfunded nonqualified benefit plans to provide supplemental retirement and deferred compensation benefits to certain key employees. Certain assets related to these plans have been set aside in a grantor trust commonly known as a “Rabbi Trust.” PSEG classifies investments in the Rabbi Trust as available-for-sale. The following tables show the fair values, gross unrealized gains and losses and amortized cost basis for the securities held in the Rabbi Trust. As of September 30, 2015 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 11 $ 9 $ — $ 20 Debt Securities Government Obligations 106 1 (1 ) 106 Other Debt Securities 86 — (2 ) 84 Total Debt Securities 192 1 (3 ) 190 Other Securities 1 — — 1 Total Rabbi Trust Available-for-Sale Securities $ 204 $ 10 $ (3 ) $ 211 As of December 31, 2014 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 12 $ 11 $ — $ 23 Debt Securities Government Obligations 89 2 — 91 Other Debt Securities 74 1 — 75 Total Debt Securities 163 3 — 166 Other Securities 2 — — 2 Total Rabbi Trust Available-for-Sale Securities $ 177 $ 14 $ — $ 191 The amounts in the preceding tables do not include receivables and payables for Rabbi Trust Fund transactions which have not settled at the end of each period. Such amounts are included in Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets as shown in the following table. As of As of September 30, December 31, Millions Accounts Receivable $ 1 $ 1 Accounts Payable $ 1 $ — The following table shows the value of securities in the Rabbi Trust Fund that have been in an unrealized loss position for less than and greater than 12 months. As of September 30, 2015 As of December 31, 2014 Less Than 12 Months Greater Than 12 Months Less Than 12 Months Greater Than 12 Months Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Millions Equity Securities (A) $ — $ — $ — $ — $ — $ — $ — $ — Debt Securities Government Obligations (B) 47 (2 ) 2 — 2 — — — Other Debt Securities (C) 41 (1 ) 9 — 24 — — — Total Debt Securities 88 (3 ) 11 — 26 — — — Rabbi Trust Available-for-Sale Securities $ 88 $ (3 ) $ 11 $ — $ 26 $ — $ — $ — (A) Equity Securities—Investments in marketable equity securities within the Rabbi Trust Fund are through a mutual fund which invests primarily in common stocks within a broad range of industries and sectors. (B) Debt Securities (Government)—Unrealized losses on PSEG’s Rabbi Trust investments in United States Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. Since these investments are guaranteed by the United States government or an agency of the United States government, it is not expected that these securities will settle for less than their amortized cost basis, since PSEG does not intend to sell nor will it be more-likely-than-not required to sell. PSEG does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (C) Debt Securities (Other)—PSEG’s investments in corporate bonds, collateralized mortgage obligations, asset-backed securities and municipal government obligations are limited to investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since PSEG does not intend to sell these securities nor will it be more-likely-than-not required to sell, PSEG does not consider these debt securities to be other-than-temporarily impaired as of September 30, 2015 . The proceeds from the sales of and the net realized gains (losses) on securities in the Rabbi Trust Fund were: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions Proceeds from Rabbi Trust Sales (A) $ 20 $ 419 $ 83 $ 445 Net Realized Gains (Losses) on Rabbi Trust: Gross Realized Gains $ — $ 2 $ 2 $ 4 Gross Realized Losses (1 ) (2 ) (1 ) (3 ) Net Realized Gains (Losses) on Rabbi Trust $ (1 ) $ — $ 1 $ 1 (A) Includes activity in accounts related to the liquidation of funds being transitioned to new managers. Gross realized gains disclosed in the preceding table were recognized in Other Income in the Condensed Consolidated Statements of Operations. Net unrealized gains of $4 million (after-tax) were a component of Accumulated Other Comprehensive Loss on the Condensed Consolidated Balance Sheets as of September 30, 2015 . The Rabbi Trust available-for-sale debt securities held as of September 30, 2015 had the following maturities: Time Frame Fair Value Millions Less than one year $ 5 1 - 5 years 49 6 - 10 years 39 11 - 15 years 8 16 - 20 years 9 Over 20 years 80 Total Rabbi Trust Available-for-Sale Debt Securities $ 190 The cost of these securities was determined on the basis of specific identification. PSEG periodically assesses individual securities whose fair value is less than amortized cost to determine whether the investments are considered to be other-than-temporarily impaired. For equity securities, the Rabbi Trust is invested in a commingled indexed mutual fund. Due to the commingled nature of this fund, PSEG does not have the ability to hold these securities until expected recovery. As a result, any declines in fair market value below cost are recorded as a charge to earnings. For fixed income securities, management considers its intent to sell or requirement to sell a security prior to expected recovery. In those cases where a sale is expected, any impairment would be recorded through earnings. For fixed income securities where there is no intent to sell or likely requirement to sell, management evaluates whether credit loss is a component of the impairment. If so, that portion is recorded through earnings while the noncredit loss component is recorded through Accumulated Other Comprehensive Income (Loss). The assessment of fair market value compared to cost is applied on a weighted average basis taking into account various purchase dates and initial cost of the securities. The fair value of assets in the Rabbi Trust related to PSEG, PSE&G and Power are detailed as follows: As of As of September 30, December 31, Millions PSE&G $ 42 $ 41 Power 52 45 Other 117 105 Total Rabbi Trust Available-for-Sale Securities $ 211 $ 191 |
Power [Member] | |
Schedule of Available-for-sale Securities [Line Items] | |
Available-for-Sale Securities | Available-for-Sale Securities Nuclear Decommissioning Trust (NDT) Fund Power maintains an external master nuclear decommissioning trust to fund its share of decommissioning for its five nuclear facilities upon termination of operation. The trust contains a qualified fund and a non-qualified fund. Section 468A of the Internal Revenue Code limits the amount of money that can be contributed into a qualified fund. The trust funds are managed by third party investment advisers who operate under investment guidelines developed by Power. Power classifies investments in the NDT Fund as available-for-sale. The following tables show the fair values and gross unrealized gains and losses for the securities held in the NDT Fund. As of September 30, 2015 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 667 $ 176 $ (18 ) $ 825 Debt Securities Government Obligations 445 10 (1 ) 454 Other Debt Securities 402 6 (7 ) 401 Total Debt Securities 847 16 (8 ) 855 Other Securities 35 — — 35 Total NDT Available-for-Sale Securities $ 1,549 $ 192 $ (26 ) $ 1,715 As of December 31, 2014 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 685 $ 220 $ (8 ) $ 897 Debt Securities Government Obligations 430 9 (1 ) 438 Other Debt Securities 333 9 (3 ) 339 Total Debt Securities 763 18 (4 ) 777 Other Securities 106 — — 106 Total NDT Available-for-Sale Securities $ 1,554 $ 238 $ (12 ) $ 1,780 The amounts in the preceding tables do not include receivables and payables for NDT Fund transactions which have not settled at the end of each period. Such amounts are included in Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets as shown in the following table. As of As of September 30, December 31, Millions Accounts Receivable $ 10 $ 10 Accounts Payable $ 4 $ 2 The following table shows the value of securities in the NDT Fund that have been in an unrealized loss position for less than and greater than 12 months. As of September 30, 2015 As of December 31, 2014 Less Than 12 Months Greater Than 12 Months Less Than 12 Months Greater Than 12 Months Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Millions Equity Securities (A) $ 143 $ (18 ) $ 1 $ — $ 162 $ (8 ) $ 1 $ — Debt Securities Government Obligations (B) 90 (1 ) 15 — 95 — 28 (1 ) Other Debt Securities (C) 164 (5 ) 29 (2 ) 99 (1 ) 30 (2 ) Total Debt Securities 254 (6 ) 44 (2 ) 194 (1 ) 58 (3 ) NDT Available-for-Sale Securities $ 397 $ (24 ) $ 45 $ (2 ) $ 356 $ (9 ) $ 59 $ (3 ) (A) Equity Securities—Investments in marketable equity securities within the NDT Fund are primarily in common stocks within a broad range of industries and sectors. The unrealized losses are distributed over a broad range of securities with limited impairment durations. Power does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (B) Debt Securities (Government)—Unrealized losses on Power’s NDT investments in United States Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. Since these investments are guaranteed by the United States government or an agency of the United States government, it is not expected that these securities will settle for less than their amortized cost basis, since Power does not intend to sell nor will it be more-likely-than-not required to sell. Power does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (C) Debt Securities (Other)—Power’s investments in corporate bonds, collateralized mortgage obligations, asset-backed securities and municipal government obligations are limited to investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since Power does not intend to sell these securities nor will it be more-likely-than-not required to sell, Power does not consider these debt securities to be other-than-temporarily impaired as of September 30, 2015 . The proceeds from the sales of and the net realized gains on securities in the NDT Fund were: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions Proceeds from NDT Fund Sales (A) $ 215 $ 221 $ 1,037 $ 779 Net Realized Gains (Losses) on NDT Fund: Gross Realized Gains 14 45 47 101 Gross Realized Losses (11 ) (3 ) (24 ) (12 ) Net Realized Gains (Losses) on NDT Fund $ 3 $ 42 $ 23 $ 89 (A) Includes activity in accounts related to the liquidation of funds being transitioned to new managers. Gross realized gains and gross realized losses disclosed in the preceding table were recognized in Other Income and Other Deductions, respectively, in PSEG’s and Power’s Condensed Consolidated Statements of Operations. Net unrealized gains of $82 million (after-tax) were a component of Accumulated Other Comprehensive Loss on PSEG's and Power’s Condensed Consolidated Balance Sheets as of September 30, 2015 . The NDT available-for-sale debt securities held as of September 30, 2015 had the following maturities: Time Frame Fair Value Millions Less than one year $ 8 1 - 5 years 236 6 - 10 years 201 11 - 15 years 51 16 - 20 years 51 Over 20 years 308 Total NDT Available-for-Sale Debt Securities $ 855 The cost of these securities was determined on the basis of specific identification. Power periodically assesses individual securities whose fair value is less than amortized cost to determine whether the investments are considered to be other-than-temporarily impaired. For equity securities, management considers the ability and intent to hold for a reasonable time to permit recovery in addition to the severity and duration of the loss. For fixed income securities, management considers its intent to sell or requirement to sell a security prior to expected recovery. In those cases where a sale is expected, any impairment would be recorded through earnings. For fixed income securities where there is no intent to sell or likely requirement to sell, management evaluates whether credit loss is a component of the impairment. If so, that portion is recorded through earnings while the noncredit loss component is recorded through Accumulated Other Comprehensive Income (Loss). For the nine months ended September 30, 2015 , other-than-temporary impairments of $45 million were recognized on securities in the NDT Fund. Any subsequent recoveries in the value of these securities would be recognized in Accumulated Other Comprehensive Income (Loss) unless the securities are sold, in which case, any gain would be recognized in income. The assessment of fair market value compared to cost is applied on a weighted average basis taking into account various purchase dates and initial cost of the securities. Rabbi Trust PSEG maintains certain unfunded nonqualified benefit plans to provide supplemental retirement and deferred compensation benefits to certain key employees. Certain assets related to these plans have been set aside in a grantor trust commonly known as a “Rabbi Trust.” PSEG classifies investments in the Rabbi Trust as available-for-sale. The following tables show the fair values, gross unrealized gains and losses and amortized cost basis for the securities held in the Rabbi Trust. As of September 30, 2015 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 11 $ 9 $ — $ 20 Debt Securities Government Obligations 106 1 (1 ) 106 Other Debt Securities 86 — (2 ) 84 Total Debt Securities 192 1 (3 ) 190 Other Securities 1 — — 1 Total Rabbi Trust Available-for-Sale Securities $ 204 $ 10 $ (3 ) $ 211 As of December 31, 2014 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 12 $ 11 $ — $ 23 Debt Securities Government Obligations 89 2 — 91 Other Debt Securities 74 1 — 75 Total Debt Securities 163 3 — 166 Other Securities 2 — — 2 Total Rabbi Trust Available-for-Sale Securities $ 177 $ 14 $ — $ 191 The amounts in the preceding tables do not include receivables and payables for Rabbi Trust Fund transactions which have not settled at the end of each period. Such amounts are included in Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets as shown in the following table. As of As of September 30, December 31, Millions Accounts Receivable $ 1 $ 1 Accounts Payable $ 1 $ — The following table shows the value of securities in the Rabbi Trust Fund that have been in an unrealized loss position for less than and greater than 12 months. As of September 30, 2015 As of December 31, 2014 Less Than 12 Months Greater Than 12 Months Less Than 12 Months Greater Than 12 Months Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Millions Equity Securities (A) $ — $ — $ — $ — $ — $ — $ — $ — Debt Securities Government Obligations (B) 47 (2 ) 2 — 2 — — — Other Debt Securities (C) 41 (1 ) 9 — 24 — — — Total Debt Securities 88 (3 ) 11 — 26 — — — Rabbi Trust Available-for-Sale Securities $ 88 $ (3 ) $ 11 $ — $ 26 $ — $ — $ — (A) Equity Securities—Investments in marketable equity securities within the Rabbi Trust Fund are through a mutual fund which invests primarily in common stocks within a broad range of industries and sectors. (B) Debt Securities (Government)—Unrealized losses on PSEG’s Rabbi Trust investments in United States Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. Since these investments are guaranteed by the United States government or an agency of the United States government, it is not expected that these securities will settle for less than their amortized cost basis, since PSEG does not intend to sell nor will it be more-likely-than-not required to sell. PSEG does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (C) Debt Securities (Other)—PSEG’s investments in corporate bonds, collateralized mortgage obligations, asset-backed securities and municipal government obligations are limited to investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since PSEG does not intend to sell these securities nor will it be more-likely-than-not required to sell, PSEG does not consider these debt securities to be other-than-temporarily impaired as of September 30, 2015 . The proceeds from the sales of and the net realized gains (losses) on securities in the Rabbi Trust Fund were: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions Proceeds from Rabbi Trust Sales (A) $ 20 $ 419 $ 83 $ 445 Net Realized Gains (Losses) on Rabbi Trust: Gross Realized Gains $ — $ 2 $ 2 $ 4 Gross Realized Losses (1 ) (2 ) (1 ) (3 ) Net Realized Gains (Losses) on Rabbi Trust $ (1 ) $ — $ 1 $ 1 (A) Includes activity in accounts related to the liquidation of funds being transitioned to new managers. Gross realized gains disclosed in the preceding table were recognized in Other Income in the Condensed Consolidated Statements of Operations. Net unrealized gains of $4 million (after-tax) were a component of Accumulated Other Comprehensive Loss on the Condensed Consolidated Balance Sheets as of September 30, 2015 . The Rabbi Trust available-for-sale debt securities held as of September 30, 2015 had the following maturities: Time Frame Fair Value Millions Less than one year $ 5 1 - 5 years 49 6 - 10 years 39 11 - 15 years 8 16 - 20 years 9 Over 20 years 80 Total Rabbi Trust Available-for-Sale Debt Securities $ 190 The cost of these securities was determined on the basis of specific identification. PSEG periodically assesses individual securities whose fair value is less than amortized cost to determine whether the investments are considered to be other-than-temporarily impaired. For equity securities, the Rabbi Trust is invested in a commingled indexed mutual fund. Due to the commingled nature of this fund, PSEG does not have the ability to hold these securities until expected recovery. As a result, any declines in fair market value below cost are recorded as a charge to earnings. For fixed income securities, management considers its intent to sell or requirement to sell a security prior to expected recovery. In those cases where a sale is expected, any impairment would be recorded through earnings. For fixed income securities where there is no intent to sell or likely requirement to sell, management evaluates whether credit loss is a component of the impairment. If so, that portion is recorded through earnings while the noncredit loss component is recorded through Accumulated Other Comprehensive Income (Loss). The assessment of fair market value compared to cost is applied on a weighted average basis taking into account various purchase dates and initial cost of the securities. The fair value of assets in the Rabbi Trust related to PSEG, PSE&G and Power are detailed as follows: As of As of September 30, December 31, Millions PSE&G $ 42 $ 41 Power 52 45 Other 117 105 Total Rabbi Trust Available-for-Sale Securities $ 211 $ 191 |
Pension and OPEB
Pension and OPEB | 9 Months Ended |
Sep. 30, 2015 | |
Defined Benefit Plan Disclosure [Line Items] | |
Pension and Other Postretirement Benefits (OPEB) | Pension and Other Postretirement Benefits (OPEB) PSEG sponsors several qualified and nonqualified pension plans and OPEB plans covering PSEG’s and its participating affiliates’ current and former employees who meet certain eligibility criteria. The following table provides the components of net periodic benefit costs relating to all qualified and nonqualified pension and OPEB plans on an aggregate basis. Pension and OPEB costs for PSEG, except for Servco, are detailed as follows: Pension Benefits OPEB Pension Benefits OPEB Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 2015 2014 Millions Components of Net Periodic Benefit Costs (Credit) Service Cost $ 30 $ 26 $ 5 $ 5 $ 92 $ 78 $ 16 $ 14 Interest Cost 59 58 16 18 176 176 50 52 Expected Return on Plan Assets (103 ) (99 ) (7 ) (7 ) (310 ) (299 ) (22 ) (20 ) Amortization of Net Prior Service Cost (Credit) (5 ) (5 ) (4 ) (4 ) (14 ) (14 ) (11 ) (11 ) Actuarial Loss 38 14 11 6 112 42 32 18 Total Benefit Costs (Credit) $ 19 $ (6 ) $ 21 $ 18 $ 56 $ (17 ) $ 65 $ 53 Pension and OPEB costs for PSE&G, Power and PSEG’s other subsidiaries, except for Servco, are detailed as follows: Pension Benefits OPEB Pension Benefits OPEB Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 2015 2014 Millions PSE&G $ 10 $ (4 ) $ 13 $ 12 $ 30 $ (14 ) $ 41 $ 35 Power 5 (2 ) 7 5 16 (5 ) 20 15 Other 4 — 1 1 10 2 4 3 Total Benefit Costs (Credit) $ 19 $ (6 ) $ 21 $ 18 $ 56 $ (17 ) $ 65 $ 53 During the three months ended March 31, 2015 , PSEG contributed its entire planned contributions for the year 2015 of $15 million into its pension plans and $14 million into its OPEB plan for 2015 . Servco Pension and OPEB At the direction of LIPA, effective January 1, 2014, Servco established benefit plans that provide substantially the same benefits to its employees as those previously provided by National Grid Electric Services LLC (NGES), the predecessor T&D system manager for LIPA. Since the vast majority of Servco's employees had worked under NGES' T&D operations services arrangement with LIPA, Servco's plans provide certain of those employees with pension and OPEB vested credit for prior years' services earned while working for NGES. The benefit plans cover all employees of Servco for current service. Under the OSA, all of these and any future employee benefit costs are to be funded by LIPA. See Note 3. Variable Interest Entities . These obligations, as well as the offsetting long-term receivable, are separately presented on the Condensed Consolidated Balance Sheet of PSEG. Servco amounts are not included in any of the preceding pension and OPEB benefit cost disclosures. Pension and OPEB costs of Servco are accounted for according to the OSA. Servco recognizes expenses for contributions to its pension plan trusts and for OPEB payments made to retirees. Operating Revenues are recognized for the reimbursement of these costs. Servco's pension-related revenues and costs were $17 million and $30 million for the three months and nine months ended September 30, 2015 , respectively, completing its entire planned contribution for the year 2015. Servco's pension-related revenues and costs were $21 million and $67 million for the three months and nine months ended September 30, 2014 , respectively. The OPEB-related revenues earned and costs incurred for each of the three months and nine months ended September 30, 2015 and 2014 were immaterial. |
PSE And G [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Pension and Other Postretirement Benefits (OPEB) | Pension and Other Postretirement Benefits (OPEB) PSEG sponsors several qualified and nonqualified pension plans and OPEB plans covering PSEG’s and its participating affiliates’ current and former employees who meet certain eligibility criteria. The following table provides the components of net periodic benefit costs relating to all qualified and nonqualified pension and OPEB plans on an aggregate basis. Pension and OPEB costs for PSEG, except for Servco, are detailed as follows: Pension Benefits OPEB Pension Benefits OPEB Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 2015 2014 Millions Components of Net Periodic Benefit Costs (Credit) Service Cost $ 30 $ 26 $ 5 $ 5 $ 92 $ 78 $ 16 $ 14 Interest Cost 59 58 16 18 176 176 50 52 Expected Return on Plan Assets (103 ) (99 ) (7 ) (7 ) (310 ) (299 ) (22 ) (20 ) Amortization of Net Prior Service Cost (Credit) (5 ) (5 ) (4 ) (4 ) (14 ) (14 ) (11 ) (11 ) Actuarial Loss 38 14 11 6 112 42 32 18 Total Benefit Costs (Credit) $ 19 $ (6 ) $ 21 $ 18 $ 56 $ (17 ) $ 65 $ 53 Pension and OPEB costs for PSE&G, Power and PSEG’s other subsidiaries, except for Servco, are detailed as follows: Pension Benefits OPEB Pension Benefits OPEB Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 2015 2014 Millions PSE&G $ 10 $ (4 ) $ 13 $ 12 $ 30 $ (14 ) $ 41 $ 35 Power 5 (2 ) 7 5 16 (5 ) 20 15 Other 4 — 1 1 10 2 4 3 Total Benefit Costs (Credit) $ 19 $ (6 ) $ 21 $ 18 $ 56 $ (17 ) $ 65 $ 53 During the three months ended March 31, 2015 , PSEG contributed its entire planned contributions for the year 2015 of $15 million into its pension plans and $14 million into its OPEB plan for 2015 . Servco Pension and OPEB At the direction of LIPA, effective January 1, 2014, Servco established benefit plans that provide substantially the same benefits to its employees as those previously provided by National Grid Electric Services LLC (NGES), the predecessor T&D system manager for LIPA. Since the vast majority of Servco's employees had worked under NGES' T&D operations services arrangement with LIPA, Servco's plans provide certain of those employees with pension and OPEB vested credit for prior years' services earned while working for NGES. The benefit plans cover all employees of Servco for current service. Under the OSA, all of these and any future employee benefit costs are to be funded by LIPA. See Note 3. Variable Interest Entities . These obligations, as well as the offsetting long-term receivable, are separately presented on the Condensed Consolidated Balance Sheet of PSEG. Servco amounts are not included in any of the preceding pension and OPEB benefit cost disclosures. Pension and OPEB costs of Servco are accounted for according to the OSA. Servco recognizes expenses for contributions to its pension plan trusts and for OPEB payments made to retirees. Operating Revenues are recognized for the reimbursement of these costs. Servco's pension-related revenues and costs were $17 million and $30 million for the three months and nine months ended September 30, 2015 , respectively, completing its entire planned contribution for the year 2015. Servco's pension-related revenues and costs were $21 million and $67 million for the three months and nine months ended September 30, 2014 , respectively. The OPEB-related revenues earned and costs incurred for each of the three months and nine months ended September 30, 2015 and 2014 were immaterial. |
Power [Member] | |
Defined Benefit Plan Disclosure [Line Items] | |
Pension and Other Postretirement Benefits (OPEB) | Pension and Other Postretirement Benefits (OPEB) PSEG sponsors several qualified and nonqualified pension plans and OPEB plans covering PSEG’s and its participating affiliates’ current and former employees who meet certain eligibility criteria. The following table provides the components of net periodic benefit costs relating to all qualified and nonqualified pension and OPEB plans on an aggregate basis. Pension and OPEB costs for PSEG, except for Servco, are detailed as follows: Pension Benefits OPEB Pension Benefits OPEB Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 2015 2014 Millions Components of Net Periodic Benefit Costs (Credit) Service Cost $ 30 $ 26 $ 5 $ 5 $ 92 $ 78 $ 16 $ 14 Interest Cost 59 58 16 18 176 176 50 52 Expected Return on Plan Assets (103 ) (99 ) (7 ) (7 ) (310 ) (299 ) (22 ) (20 ) Amortization of Net Prior Service Cost (Credit) (5 ) (5 ) (4 ) (4 ) (14 ) (14 ) (11 ) (11 ) Actuarial Loss 38 14 11 6 112 42 32 18 Total Benefit Costs (Credit) $ 19 $ (6 ) $ 21 $ 18 $ 56 $ (17 ) $ 65 $ 53 Pension and OPEB costs for PSE&G, Power and PSEG’s other subsidiaries, except for Servco, are detailed as follows: Pension Benefits OPEB Pension Benefits OPEB Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 2015 2014 Millions PSE&G $ 10 $ (4 ) $ 13 $ 12 $ 30 $ (14 ) $ 41 $ 35 Power 5 (2 ) 7 5 16 (5 ) 20 15 Other 4 — 1 1 10 2 4 3 Total Benefit Costs (Credit) $ 19 $ (6 ) $ 21 $ 18 $ 56 $ (17 ) $ 65 $ 53 During the three months ended March 31, 2015 , PSEG contributed its entire planned contributions for the year 2015 of $15 million into its pension plans and $14 million into its OPEB plan for 2015 . Servco Pension and OPEB At the direction of LIPA, effective January 1, 2014, Servco established benefit plans that provide substantially the same benefits to its employees as those previously provided by National Grid Electric Services LLC (NGES), the predecessor T&D system manager for LIPA. Since the vast majority of Servco's employees had worked under NGES' T&D operations services arrangement with LIPA, Servco's plans provide certain of those employees with pension and OPEB vested credit for prior years' services earned while working for NGES. The benefit plans cover all employees of Servco for current service. Under the OSA, all of these and any future employee benefit costs are to be funded by LIPA. See Note 3. Variable Interest Entities . These obligations, as well as the offsetting long-term receivable, are separately presented on the Condensed Consolidated Balance Sheet of PSEG. Servco amounts are not included in any of the preceding pension and OPEB benefit cost disclosures. Pension and OPEB costs of Servco are accounted for according to the OSA. Servco recognizes expenses for contributions to its pension plan trusts and for OPEB payments made to retirees. Operating Revenues are recognized for the reimbursement of these costs. Servco's pension-related revenues and costs were $17 million and $30 million for the three months and nine months ended September 30, 2015 , respectively, completing its entire planned contribution for the year 2015. Servco's pension-related revenues and costs were $21 million and $67 million for the three months and nine months ended September 30, 2014 , respectively. The OPEB-related revenues earned and costs incurred for each of the three months and nine months ended September 30, 2015 and 2014 were immaterial. |
Commitments and Contingent Liab
Commitments and Contingent Liabilities | 9 Months Ended |
Sep. 30, 2015 | |
Loss Contingencies [Line Items] | |
Commitments and Contingent Liabilities | Commitments and Contingent Liabilities Guaranteed Obligations Power’s activities primarily involve the purchase and sale of energy and related products under transportation, physical, financial and forward contracts at fixed and variable prices. These transactions are with numerous counterparties and brokers that may require cash, cash-related instruments or guarantees. Power has unconditionally guaranteed payments to counterparties by its subsidiaries in commodity-related transactions in order to • support current exposure, interest and other costs on sums due and payable in the ordinary course of business, and • obtain credit. Under these agreements, guarantees cover lines of credit between entities and are often reciprocal in nature. The exposure between counterparties can move in either direction. In order for Power to incur a liability for the face value of the outstanding guarantees, its subsidiaries would have to • fully utilize the credit granted to them by every counterparty to whom Power has provided a guarantee, and • all of the related contracts would have to be “out-of-the-money” (if the contracts are terminated, Power would owe money to the counterparties). Power believes the probability of this result is unlikely. For this reason, Power believes that the current exposure at any point in time is a more meaningful representation of the potential liability under these guarantees. This current exposure consists of the net of accounts receivable and accounts payable and the forward value on open positions, less any collateral posted. Power is subject to • counterparty collateral calls related to commodity contracts, and • certain creditworthiness standards as guarantor under performance guarantees of its subsidiaries. Changes in commodity prices can have a material impact on collateral requirements under such contracts, which are posted and received primarily in the form of cash and letters of credit. Power also routinely enters into futures and options transactions for electricity and natural gas as part of its operations. These futures contracts usually require a cash margin deposit with brokers, which can change based on market movement and in accordance with exchange rules. In addition to the guarantees discussed above, Power has also provided payment guarantees to third parties on behalf of its affiliated companies. These guarantees support various other non-commodity related contractual obligations. The face value of Power's outstanding guarantees, current exposure and margin positions as of September 30, 2015 and December 31, 2014 are shown as follows: As of As of September 30, December 31, Millions Face Value of Outstanding Guarantees $ 1,733 $ 1,814 Exposure under Current Guarantees $ 184 $ 273 Letters of Credit Margin Posted $ 178 $ 159 Letters of Credit Margin Received $ 80 $ 40 Cash Deposited and Received: Counterparty Cash Margin Deposited $ — $ — Counterparty Cash Margin Received $ (44 ) $ (13 ) Net Broker Balance Deposited (Received) $ 4 $ 115 In the Event Power were to Lose its Investment Grade Rating: Additional Collateral that could be Required $ 796 $ 945 Liquidity Available under PSEG’s and Power’s Credit Facilities to Post Collateral $ 3,375 $ 3,495 Additional Amounts Posted: Other Letters of Credit $ 47 $ 45 As part of determining credit exposure, Power nets receivables and payables with the corresponding net energy contract balances. See Note 10. Financial Risk Management Activities for further discussion. In accordance with PSEG's accounting policy, where it is applicable, cash (received)/deposited is allocated against derivative asset and liability positions with the same counterparty on the face of the Balance Sheet. The remaining balances of net cash (received)/deposited after allocation are generally included in Accounts Payable and Receivable, respectively. In the event of a deterioration of Power’s credit rating to below investment grade, which would represent a three level downgrade from its current S&P and Moody’s ratings, many of these agreements allow the counterparty to demand further performance assurance. See table above. In addition to amounts for outstanding guarantees, current exposure and margin positions, PSEG and Power had posted letters of credit to support Power's various other non-energy contractual and environmental obligations. See preceding table. PSEG had also issued a $106 million guarantee to support Power's payment obligations related to its equity interest in the PennEast natural gas pipeline and a $21 million guarantee to support Power's payment obligations related to construction of a 755 MW gas-fired combined cycle generating station in Maryland. In the event that PSEG were to be downgraded to below investment grade and failed to meet minimum net worth requirements, these guarantees would each have to be replaced by a letter of credit. Environmental Matters Passaic River Historic operations of PSEG companies and the operations of hundreds of other companies along the Passaic and Hackensack Rivers are alleged by Federal and State agencies to have discharged substantial contamination into the Passaic River/Newark Bay Complex in violation of various statutes as discussed as follows. Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 (CERCLA) In 2002, the U.S. Environmental Protection Agency (EPA) determined that a 17 -mile stretch of the lower Passaic River from Newark to Clifton, New Jersey is a “Superfund” site under CERCLA. This designation allows the EPA to clean up such sites and to compel responsible parties to perform cleanups or reimburse the government for cleanups led by the EPA. The EPA further determined that there was a need to perform a comprehensive study of the entire 17 -miles of the lower Passaic River. PSE&G and certain of its predecessors conducted operations at properties in this area of the Passaic River. The properties included one operating electric generating station (Essex Site), which was transferred to Power, one former generating station and four former manufactured gas plant (MGP) sites. In early 2007, 73 Potentially Responsible Parties (PRPs), including PSE&G and Power, formed a Cooperating Parties Group (CPG) and agreed to assume responsibility for conducting a Remedial Investigation and Feasibility Study (RI/FS) of the 17 miles of the lower Passaic River. At such time, the CPG also agreed to allocate, on an interim basis, the associated costs of the RI/FS among its members on the basis of a mutually agreed upon formula. For the purpose of this interim allocation, which has been revised as parties have exited the CPG, approximately seven percent of the RI/FS costs are currently deemed attributable to PSE&G’s former MGP sites and approximately one percent is attributable to Power’s generating stations. These interim allocations are not binding on PSE&G or Power in terms of their respective shares of the costs that will be ultimately required to remediate the 17 miles of the lower Passaic River. PSEG has provided notice to insurers concerning this potential claim. In June 2008, the EPA and Tierra Solutions, Inc. (Tierra) and Maxus Energy Corporation (Maxus) entered into an early action agreement whereby Tierra/Maxus agreed to remove a portion of the heavily dioxin-contaminated sediment located in the lower Passaic River. The portion of the Passaic River identified in this agreement was located immediately adjacent to Tierra/Maxus’ predecessor company’s (Diamond Shamrock) facility. Pursuant to the agreement between the EPA and Tierra/Maxus, the estimated cost for the work to remove the sediment in this location was $80 million . Phase I of the removal work has been completed. Pursuant to this agreement, Tierra/Maxus have reserved their rights to seek contribution for these removal costs from the other PRPs, including Power and PSE&G. This agreement and the work undertaken pursuant to the action agreement will not affect the ultimate remedy that the EPA will select for the remediation of the 17-mile stretch of the lower Passaic River. In 2012, Tierra/Maxus withdrew from the CPG and refused to participate as members going forward, other than with respect to their obligation to fund the EPA’s portion of its RI/FS oversight costs. At such time, the remaining members of the CPG, in agreement with the EPA, commenced the removal of certain contaminated sediments at Passaic River Mile 10.9 at an estimated cost of $25 million to $30 million . PSEG’s share of the cost of that effort is approximately three percent . The remaining CPG members have reserved their rights to seek reimbursement from Tierra/Maxus for the costs of the River Mile 10.9 removal. On April 11, 2014, the EPA released its revised draft “Focused Feasibility Study” (FFS) which contemplates the removal of 4.3 million cubic yards of sediment from the bottom of the lower eight miles of the 17-mile stretch of the Passaic River. The revised draft FFS sets forth various alternatives for remediating this portion of the Passaic River. The EPA’s estimated costs to remediate the lower eight miles of the Passaic River range from $365 million for a targeted remedy to $3.3 billion for a deep dredge of this portion of the Passaic River. The EPA also identified in the revised draft FFS its preferred alternative, which would involve dredging the lower eight miles of the river bank-to-bank and installing an engineered cap. The estimated cost in the revised draft FFS for the EPA's preferred alternative is $1.7 billion . No provisional cost allocation has been made by the CPG for the work contemplated by the revised draft FFS, and the work contemplated by the revised draft FFS is not subject to the CPG’s cost sharing allocation agreed to in connection with the removal work for River Mile 10.9 or in connection with the conduct of the RI/FS. The revised draft FFS was subject to a public comment period, and remains subject to the EPA’s response to comments submitted, a design phase and at least an estimated five years for completion of the work. The public comment period for the revised draft FFS closed on August 21, 2014. Over 300 comments were submitted by a variety of entities potentially impacted by the revised draft FFS, including the CPG, individual companies, municipalities, public officials, citizens groups, Amtrak, NJ Transit and others. The CPG, which consisted of 60 members as of September 30, 2015 , provided a draft RI and draft FS, both relating to the entire 17 miles of the lower Passaic River, to the EPA on February 18, 2015 and April 30, 2015, respectively. The estimated total cost of the RI/FS is approximately $151 million , which the CPG continues to incur. Of the estimated $151 million , as of August 31, 2015 , the CPG had spent approximately $141 million , of which PSEG's total share was approximately $9 million . The draft FS sets forth various alternatives for remediating the lower Passaic River. The draft FS sets forth the CPG’s estimated costs to remediate the lower 17 miles of the Passaic River which range from approximately $518 million to $3.2 billion . The CPG identified a targeted remedy in the draft FS which would involve removal, treatment and disposal of contaminated sediments taken from targeted locations within the entire 17 miles of the lower Passaic River. The estimated cost in the draft FS for the targeted remedy ranges from approximately $518 million to $772 million . No provisional cost allocation has been made by the CPG for the work contemplated by the draft FS. However, based on (i) the low end of the range of the current estimates of costs to remediate, (ii) PSE&G's and Power's estimates of their share of those costs, and (iii) the continued ability of PSE&G to recover such costs in its rates, PSE&G accrued a $10 million Environmental Costs Liability and a corresponding Regulatory Asset and Power accrued a $3 million Other Noncurrent Liability and a corresponding O&M Expense in the first quarter of 2015. The EPA will consider the comments received on its revised draft FFS and is expected to consider the CPG’s RI/FS prior to issuing a Record of Decision (ROD) of a selected remedy for the lower Passaic River. The EPA has broad authority to implement its selected remedy through the ROD and PSEG cannot at this time predict how the implementation of the ROD might impact PSE&G's and Power's ultimate liability. Until (i) the RI/FS is finalized, (ii) a final remedy is determined by the EPA or through litigation, (iii) PSE&G's and Power’s respective shares of the costs, both in the aggregate as well as individually, are determined, and (iv) PSE&G’s continued ability to recover the costs in its rates is determined, it is not possible to predict this matter’s ultimate impact on our financial statements. It is possible that PSE&G and Power will record additional costs beyond what they have accrued, and that such costs could be material, but PSEG cannot at the current time estimate the amount or range of any additional costs. Natural Resource Damage Claims In 2003, the New Jersey Department of Environmental Protection (NJDEP) directed PSEG, PSE&G and 56 other PRPs to arrange for a natural resource damage assessment and interim compensatory restoration of natural resource injuries along the lower Passaic River and its tributaries pursuant to the New Jersey Spill Compensation and Control Act. The NJDEP alleged that hazardous substances had been discharged from the Essex Site and the Harrison Site. The NJDEP estimated the cost of interim natural resource injury restoration activities along the lower Passaic River at approximately $950 million . In 2007, agencies of the United States Department of Commerce and the United States Department of the Interior (the Passaic River federal trustees) sent letters to PSE&G and other PRPs inviting participation in an assessment of injuries to natural resources that the agencies intended to perform. In 2008, PSEG and a number of other PRPs agreed to share certain immaterial costs the trustees have incurred and will incur going forward, and to work with the trustees to explore whether some or all of the trustees’ claims can be resolved in a cooperative fashion. That effort is continuing. PSE&G and Power are unable to estimate their respective portions of the possible loss or range of loss related to this matter. Newark Bay Study Area The EPA has established the Newark Bay Study Area, which it defines as Newark Bay and portions of the Hackensack River, the Arthur Kill and the Kill Van Kull. In August 2006, the EPA sent PSEG and 11 other entities notices that it considered each of the entities to be a PRP with respect to contamination in the Study Area. The notice letter requested that the PRPs fund an EPA-approved study in the Newark Bay Study Area. The notice stated the EPA’s belief that hazardous substances were released from sites owned by PSEG companies and located on the Hackensack River, including two operating electric generating stations (Hudson and Kearny sites) and one former MGP site. PSEG has participated in and partially funded the second phase of this study. Notices to fund the next phase of the study have been received but PSEG has not consented to fund the third phase. PSE&G and Power are unable to estimate their respective portions of the possible loss or range of loss related to this matter. MGP Remediation Program PSE&G is working with the NJDEP to assess, investigate and remediate environmental conditions at its former MGP sites. To date, 38 sites requiring some level of remedial action have been identified. Based on its current studies, PSE&G has determined that the estimated cost to remediate all MGP sites to completion could range between $450 million and $518 million through 2021, including its $10 million share for the Passaic River as discussed above. Since no amount within the range is considered to be most likely, PSE&G has recorded a liability of $450 million as of September 30, 2015 . Of this amount, $73 million was recorded in Other Current Liabilities and $377 million was reflected as Environmental Costs in Noncurrent Liabilities. PSE&G has recorded a $450 million Regulatory Asset with respect to these costs. PSE&G periodically updates its studies taking into account any new regulations or new information which could impact future remediation costs and adjusts its recorded liability accordingly. Prevention of Significant Deterioration (PSD)/New Source Review (NSR) The PSD/NSR regulations, promulgated under the Clean Air Act (CAA), require major sources of certain air pollutants to obtain permits, install pollution control technology and obtain offsets, in some circumstances, when those sources undergo a “major modification,” as defined in the regulations. The federal government may order companies that are not in compliance with the PSD/NSR regulations to install the best available control technology at the affected plants and to pay monetary penalties ranging from $25,000 to $37,500 per day for each violation, depending upon when the alleged violation occurred. In 2009, the EPA issued a notice of violation to Power and the other owners of the Keystone coal-fired plant in Pennsylvania, alleging, among other things, that various capital improvement projects were completed at the plant which are considered modifications (or major modifications) causing significant net emission increases of PSD/NSR air pollutants, beginning in 1985 for Keystone Unit 1 and in 1984 for Keystone Unit 2. The notice of violation states that none of these modifications underwent the PSD/NSR permitting process prior to being put into service, which the EPA alleges was required under the CAA. The notice of violation states that the EPA may issue an order requiring compliance with the relevant CAA provisions and may seek injunctive relief and/or civil penalties. Power owns approximately 23% of the plant. Power cannot predict the outcome of this matter. Clean Water Act Permit Renewals Pursuant to the Federal Water Pollution Control Act (FWPCA), National Pollutant Discharge Elimination System permits expire within five years of their effective date. In order to renew these permits, but allow a plant to continue to operate, an owner or operator must file a permit application no later than six months prior to expiration of the permit. States with delegated federal authority for this program manage these permits. The New Jersey Department of Environmental Protection (NJDEP) manages the permits under the New Jersey Pollutant Discharge Elimination System (NJPDES) program. Connecticut and New York also have permits to manage their respective pollutant discharge elimination system programs. In 2001, the NJDEP issued a renewed NJPDES permit for Salem, expiring in July 2006, allowing for the continued operation of Salem with its existing cooling water intake system. In February 2006, Power filed with the NJDEP a renewal application allowing Salem to continue operating under its existing NJPDES permit until a new permit is issued. On June 30, 2015, the NJDEP issued a draft Salem permit. The draft permit does not require installation of cooling towers and allows Salem to continue to operate utilizing the existing once-through cooling water system with certain required system modifications. The draft permit was subject to a public notice and comment period. The NJDEP may make revisions before issuing the final permit expected during the first half of 2016. Power participated in the NJDEP’s August 5, 2015 public hearing and submitted comments on the draft permit on September 18, 2015. On May 19, 2014, the EPA issued a final rule that establishes new requirements for the regulation of cooling water intake structures at existing power plants and industrial facilities with a design flow of more than two million gallons of water per day. On August 15, 2014, the EPA established October 14, 2014 as the effective date for each state to implement the provisions of the rule going forward when considering the renewal of permits for existing facilities on a case by case basis. On September 5, 2014, several environmental non-governmental groups and certain energy industry groups filed motions to litigate the provisions of the rule. This case is pending at the U.S. Second Circuit Court of Appeals. In two related actions on October 17, 2014 and November 20, 2014, several environmental non-governmental groups initiated challenges to the endangered species act provisions of the 316 (b) rule. Power is unable to determine the ultimate impact of these actions on the implementation of the rule. State permitting decisions could have a material impact on Power’s ability to renew permits at its larger once-through cooled plants, including Salem, Hudson, Mercer, Bridgeport and possibly Sewaren and New Haven, without making significant upgrades to existing intake structures and cooling systems. The costs of those upgrades to one or more of Power’s once-through cooled plants would be material, and would require economic review to determine whether to continue operations at these facilities. For example, in Power’s application to renew its Salem permit, filed with the NJDEP in February 2006, the estimated costs for adding cooling towers for Salem were approximately $1.0 billion , of which Power’s share would have been approximately $575 million . The filing has not been updated. Currently, potential costs associated with any closed cycle cooling requirements are not included in Power’s forecasted capital expenditures. Power is unable to predict the outcome of these permitting decisions and the effect, if any, that they may have on Power's future capital requirements, financial condition or results of operations. Bridgeport Harbor National Pollutant Discharge Elimination System (NPDES) Permit Compliance In April 2015, Power determined that monitoring and reporting practices related to certain permitted wastewater discharges at its Bridgeport Harbor station may have violated conditions of the station's NPDES permit and applicable regulations and could subject it to fines and penalties. Power has notified the Connecticut Department of Energy and Environmental Protection of the issues and has taken actions to investigate and resolve the potential non-compliance. At this early stage Power cannot predict the impact of this matter. Steam Electric Effluent Guidelines On September 30, 2015, the EPA issued a new Effluent Guidelines Limitation Rule for steam electric generating units. The rule establishes new best available technology economically achievable (BAT) standards for fly ash transport water, bottom ash transport water, flue gas desulfurization and flue gas mercury control wastewater. The EPA provides an implementation period for currently existing discharges of three years or up to eight years if a facility needs more time to implement equipment upgrades and provide supporting information to its permitting authority. In the intervening time period, existing discharge standards continue to apply. Power's Mercer and Bridgeport Harbor stations have bottom ash transport water discharges that are regulated under this rule. Power is unable to predict if these new standards will have a material impact on Power's future capital requirements, financial condition or results of operations. Coal Combustion Residuals (CCRs) On December 19, 2014, the EPA issued a final rule which regulates CCRs as non-hazardous and requires that facility owners implement a series of actions to close or upgrade existing CCR surface impoundments and/or landfills. It also establishes new provisions for the construction of new surface impoundments and landfills. Power's Hudson and Mercer generating stations, along with its co-owned Keystone and Conemaugh stations, are subject to the provisions of this rule. On April 17, 2015, the final rule was published with an effective date of October 19, 2015. Accordingly in June 2015, Power recorded an additional asset retirement obligation to comply with the final CCR rule which was not material to Power’s results of operations, financial condition or cash flows. Basic Generation Service (BGS) and Basic Gas Supply Service (BGSS) PSE&G obtains its electric supply requirements through the annual New Jersey BGS auctions for two categories of customers who choose not to purchase electric supply from third party suppliers. The first category, which represents about 80% of PSE&G's load requirement, are residential and smaller commercial and industrial customers (BGS-Residential Small Commercial Pricing (RSCP)). The second category are larger customers that exceed a BPU-established load (kW) threshold (BGS-Commercial and Industrial Pricing (CIEP)). Pursuant to applicable BPU rules, PSE&G enters into the Supplier Master Agreement with the winners of these BGS auctions following the BPU’s approval of the auction results. PSE&G has entered into contracts with winning BGS suppliers, including Power, to purchase BGS for PSE&G’s load requirements. The winners of the auction (including Power) are responsible for fulfilling all the requirements of a PJM Load Serving Entity including the provision of capacity, energy, ancillary services, transmission and any other services required by PJM. BGS suppliers assume all volume risk and customer migration risk and must satisfy New Jersey’s renewable portfolio standards. The BGS-CIEP auction is for a one-year supply period from June 1 to May 31 with the BGS-CIEP auction price measured in dollars per MW-day for capacity. The final price for the BGS-CIEP auction year commencing June 1, 2015 is $272.78 per MW-day, replacing the BGS-CIEP auction year price ending May 31, 2015 of $282.04 per MW-day. Energy for BGS-CIEP is priced at hourly PJM locational marginal prices for the contract period. PSE&G contracts for its anticipated BGS-RSCP load on a three-year rolling basis, whereby each year one-third of the load is procured for a three-year period. The contract prices in dollars per MWh for the BGS-RSCP supply, as well as the approximate load, are as follows: Auction Year 2012 2013 2014 2015 36-Month Terms Ending May 2015 May 2016 May 2017 May 2018 (A) Load (MW) 2,900 2,800 2,800 2,900 $ per MWh $83.88 $92.18 $97.39 $99.54 (A) Prices set for the 2015 BGS auction year became effective on June 1, 2015 when the 2012 BGS auction agreements expired. Power seeks to mitigate volatility in its results by contracting in advance for the sale of most of its anticipated electric output as well as its anticipated fuel needs. As part of its objective, Power has entered into contracts to directly supply PSE&G and other New Jersey electric distribution companies (EDCs) with a portion of their respective BGS requirements through the New Jersey BGS auction process, described above. PSE&G has a full-requirements contract with Power to meet the gas supply requirements of PSE&G’s gas customers. Power has entered into hedges for a portion of these anticipated BGSS obligations, as permitted by the BPU. The BPU permits PSE&G to recover the cost of gas hedging up to 115 billion cubic feet or 80% of its residential gas supply annual requirements through the BGSS tariff. Current plans call for Power to hedge on behalf of PSE&G approximately 70 billion cubic feet or 50% of its residential gas supply annual requirements. For additional information, see Note 17. Related-Party Transactions . Minimum Fuel Purchase Requirements Power’s nuclear fuel strategy is to maintain certain levels of uranium and to make periodic purchases to support such levels. As such, the commitments referred to in the following table may include estimated quantities to be purchased that deviate from contractual nominal quantities. Power’s nuclear fuel commitments cover approximately 100% of its estimated uranium, enrichment and fabrication requirements through 2017 and a significant portion through 2020 at Salem, Hope Creek and Peach Bottom. Power has various long-term fuel purchase commitments for coal through 2018 to support its fossil generation stations. Power also has various multi-year contracts for natural gas and firm transportation and storage capacity for natural gas that are primarily used to meet its obligations to PSE&G. When there is excess delivery capacity available, Power can use the gas to supply its fossil generating stations. As of September 30, 2015 , the total minimum purchase requirements included in these commitments were as follows: Fuel Type Power's Share of Commitments through 2019 Millions Nuclear Fuel Uranium $ 440 Enrichment $ 345 Fabrication $ 179 Natural Gas $ 1,001 Coal $ 331 Regulatory Proceedings FERC Compliance In the first quarter of 2014, Power discovered that it incorrectly calculated certain components of its cost-based bids for its New Jersey fossil generating units in the PJM energy market. Upon discovery of the errors, PSEG retained outside counsel to assist in the conduct of an investigation into the matter. As the investigation proceeded, additional pricing errors in the bids were identified. It was further determined that the quantity of energy that Power offered into the energy market for its fossil peaking units differed from the amount for which Power was compensated in the capacity market for those units. PSEG informed FERC, PJM and the PJM Independent Market Monitor (IMM) of these additional issues, corrected the identified errors and modified the bid quantities for its peaking units. Power continues to implement procedures to help mitigate the risk of similar issues occurring in the future. On September 2, 2014, FERC Staff initiated a preliminary, non-public staff investigation into the matter. This investigation, which is ongoing, could result in FERC seeking disgorgement of any over-collected amounts, civil penalties and non-financial remedies. During the three months ended March 31, 2014 , based upon its best estimate available at the time, Power recorded a charge to income in the amount of $25 million related to this matter. It is not possible at this time to reasonably estimate the potential range of loss or full impact or predict any resulting penalties or other costs associated with this matter, or the applicability of mitigating factors. As new information becomes available or future developments occur in this investigation, it is possible that Power will record additional estimated losses and such additional losses may be material. New Jersey Clean Energy Program In June 2015, the BPU established the funding level for fiscal year 2016 applicable to its Renewable Energy and Energy Efficiency programs. The fiscal year 2016 aggregate funding for all EDCs is $345 million with PSE&G's share of the funding at $200 million . PSE&G has a current liability of $185 million as of September 30, 2015 for its outstanding share of the fiscal year 2016 and remaining fiscal year 2015 funding, respectively. The liability is reduced as normal payments are made. The liability has been recorded with an offsetting Regulatory Asset, since the costs associated with this program are recovered from PSE&G ratepayers through the Societal Benefits Charge (SBC). Superstorm Sandy In late October 2012, Superstorm Sandy caused severe damage to PSE&G's T&D system throughout its service territory as well as to some of Power's generation infrastructure in the northern part of New Jersey. Strong winds and the resulting storm surge caused damage to switching stations, substations and generating infrastructure. PSEG maintains insurance coverage against loss or damage to plants and certain properties, subject to certain exceptions and limitations, to the extent such property is usually insured and insurance is available at a reasonable cost. In June 2013, PSEG, PSE&G and Power filed suit in New Jersey state court (NJ Court) against its insurance carriers seeking an interpretation that the insurance policies cover their losses resulting from damage caused by Superstorm Sandy's storm surge. As of December 31, 2012, PSE&G had incurred approximately $295 million of costs to restore service to PSE&G's distribution and transmission systems and $5 million to repair its infrastructure and return it to pre-storm conditions. Of the costs incurred, approximately $40 million was recognized in O&M Expense, $75 million was recorded as Property, Plant and Equipment and $180 million was recorded as a Regulatory Asset because such costs were deferred as approved by the BPU under an Order received in December 2012. Of the $295 million , $36 million related to insured property. In 2012, PSE&G recognized $6 million of insurance recoveries, which were deferred. There were no s |
PSE And G [Member] | |
Loss Contingencies [Line Items] | |
Commitments and Contingent Liabilities | Commitments and Contingent Liabilities Guaranteed Obligations Power’s activities primarily involve the purchase and sale of energy and related products under transportation, physical, financial and forward contracts at fixed and variable prices. These transactions are with numerous counterparties and brokers that may require cash, cash-related instruments or guarantees. Power has unconditionally guaranteed payments to counterparties by its subsidiaries in commodity-related transactions in order to • support current exposure, interest and other costs on sums due and payable in the ordinary course of business, and • obtain credit. Under these agreements, guarantees cover lines of credit between entities and are often reciprocal in nature. The exposure between counterparties can move in either direction. In order for Power to incur a liability for the face value of the outstanding guarantees, its subsidiaries would have to • fully utilize the credit granted to them by every counterparty to whom Power has provided a guarantee, and • all of the related contracts would have to be “out-of-the-money” (if the contracts are terminated, Power would owe money to the counterparties). Power believes the probability of this result is unlikely. For this reason, Power believes that the current exposure at any point in time is a more meaningful representation of the potential liability under these guarantees. This current exposure consists of the net of accounts receivable and accounts payable and the forward value on open positions, less any collateral posted. Power is subject to • counterparty collateral calls related to commodity contracts, and • certain creditworthiness standards as guarantor under performance guarantees of its subsidiaries. Changes in commodity prices can have a material impact on collateral requirements under such contracts, which are posted and received primarily in the form of cash and letters of credit. Power also routinely enters into futures and options transactions for electricity and natural gas as part of its operations. These futures contracts usually require a cash margin deposit with brokers, which can change based on market movement and in accordance with exchange rules. In addition to the guarantees discussed above, Power has also provided payment guarantees to third parties on behalf of its affiliated companies. These guarantees support various other non-commodity related contractual obligations. The face value of Power's outstanding guarantees, current exposure and margin positions as of September 30, 2015 and December 31, 2014 are shown as follows: As of As of September 30, December 31, Millions Face Value of Outstanding Guarantees $ 1,733 $ 1,814 Exposure under Current Guarantees $ 184 $ 273 Letters of Credit Margin Posted $ 178 $ 159 Letters of Credit Margin Received $ 80 $ 40 Cash Deposited and Received: Counterparty Cash Margin Deposited $ — $ — Counterparty Cash Margin Received $ (44 ) $ (13 ) Net Broker Balance Deposited (Received) $ 4 $ 115 In the Event Power were to Lose its Investment Grade Rating: Additional Collateral that could be Required $ 796 $ 945 Liquidity Available under PSEG’s and Power’s Credit Facilities to Post Collateral $ 3,375 $ 3,495 Additional Amounts Posted: Other Letters of Credit $ 47 $ 45 As part of determining credit exposure, Power nets receivables and payables with the corresponding net energy contract balances. See Note 10. Financial Risk Management Activities for further discussion. In accordance with PSEG's accounting policy, where it is applicable, cash (received)/deposited is allocated against derivative asset and liability positions with the same counterparty on the face of the Balance Sheet. The remaining balances of net cash (received)/deposited after allocation are generally included in Accounts Payable and Receivable, respectively. In the event of a deterioration of Power’s credit rating to below investment grade, which would represent a three level downgrade from its current S&P and Moody’s ratings, many of these agreements allow the counterparty to demand further performance assurance. See table above. In addition to amounts for outstanding guarantees, current exposure and margin positions, PSEG and Power had posted letters of credit to support Power's various other non-energy contractual and environmental obligations. See preceding table. PSEG had also issued a $106 million guarantee to support Power's payment obligations related to its equity interest in the PennEast natural gas pipeline and a $21 million guarantee to support Power's payment obligations related to construction of a 755 MW gas-fired combined cycle generating station in Maryland. In the event that PSEG were to be downgraded to below investment grade and failed to meet minimum net worth requirements, these guarantees would each have to be replaced by a letter of credit. Environmental Matters Passaic River Historic operations of PSEG companies and the operations of hundreds of other companies along the Passaic and Hackensack Rivers are alleged by Federal and State agencies to have discharged substantial contamination into the Passaic River/Newark Bay Complex in violation of various statutes as discussed as follows. Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 (CERCLA) In 2002, the U.S. Environmental Protection Agency (EPA) determined that a 17 -mile stretch of the lower Passaic River from Newark to Clifton, New Jersey is a “Superfund” site under CERCLA. This designation allows the EPA to clean up such sites and to compel responsible parties to perform cleanups or reimburse the government for cleanups led by the EPA. The EPA further determined that there was a need to perform a comprehensive study of the entire 17 -miles of the lower Passaic River. PSE&G and certain of its predecessors conducted operations at properties in this area of the Passaic River. The properties included one operating electric generating station (Essex Site), which was transferred to Power, one former generating station and four former manufactured gas plant (MGP) sites. In early 2007, 73 Potentially Responsible Parties (PRPs), including PSE&G and Power, formed a Cooperating Parties Group (CPG) and agreed to assume responsibility for conducting a Remedial Investigation and Feasibility Study (RI/FS) of the 17 miles of the lower Passaic River. At such time, the CPG also agreed to allocate, on an interim basis, the associated costs of the RI/FS among its members on the basis of a mutually agreed upon formula. For the purpose of this interim allocation, which has been revised as parties have exited the CPG, approximately seven percent of the RI/FS costs are currently deemed attributable to PSE&G’s former MGP sites and approximately one percent is attributable to Power’s generating stations. These interim allocations are not binding on PSE&G or Power in terms of their respective shares of the costs that will be ultimately required to remediate the 17 miles of the lower Passaic River. PSEG has provided notice to insurers concerning this potential claim. In June 2008, the EPA and Tierra Solutions, Inc. (Tierra) and Maxus Energy Corporation (Maxus) entered into an early action agreement whereby Tierra/Maxus agreed to remove a portion of the heavily dioxin-contaminated sediment located in the lower Passaic River. The portion of the Passaic River identified in this agreement was located immediately adjacent to Tierra/Maxus’ predecessor company’s (Diamond Shamrock) facility. Pursuant to the agreement between the EPA and Tierra/Maxus, the estimated cost for the work to remove the sediment in this location was $80 million . Phase I of the removal work has been completed. Pursuant to this agreement, Tierra/Maxus have reserved their rights to seek contribution for these removal costs from the other PRPs, including Power and PSE&G. This agreement and the work undertaken pursuant to the action agreement will not affect the ultimate remedy that the EPA will select for the remediation of the 17-mile stretch of the lower Passaic River. In 2012, Tierra/Maxus withdrew from the CPG and refused to participate as members going forward, other than with respect to their obligation to fund the EPA’s portion of its RI/FS oversight costs. At such time, the remaining members of the CPG, in agreement with the EPA, commenced the removal of certain contaminated sediments at Passaic River Mile 10.9 at an estimated cost of $25 million to $30 million . PSEG’s share of the cost of that effort is approximately three percent . The remaining CPG members have reserved their rights to seek reimbursement from Tierra/Maxus for the costs of the River Mile 10.9 removal. On April 11, 2014, the EPA released its revised draft “Focused Feasibility Study” (FFS) which contemplates the removal of 4.3 million cubic yards of sediment from the bottom of the lower eight miles of the 17-mile stretch of the Passaic River. The revised draft FFS sets forth various alternatives for remediating this portion of the Passaic River. The EPA’s estimated costs to remediate the lower eight miles of the Passaic River range from $365 million for a targeted remedy to $3.3 billion for a deep dredge of this portion of the Passaic River. The EPA also identified in the revised draft FFS its preferred alternative, which would involve dredging the lower eight miles of the river bank-to-bank and installing an engineered cap. The estimated cost in the revised draft FFS for the EPA's preferred alternative is $1.7 billion . No provisional cost allocation has been made by the CPG for the work contemplated by the revised draft FFS, and the work contemplated by the revised draft FFS is not subject to the CPG’s cost sharing allocation agreed to in connection with the removal work for River Mile 10.9 or in connection with the conduct of the RI/FS. The revised draft FFS was subject to a public comment period, and remains subject to the EPA’s response to comments submitted, a design phase and at least an estimated five years for completion of the work. The public comment period for the revised draft FFS closed on August 21, 2014. Over 300 comments were submitted by a variety of entities potentially impacted by the revised draft FFS, including the CPG, individual companies, municipalities, public officials, citizens groups, Amtrak, NJ Transit and others. The CPG, which consisted of 60 members as of September 30, 2015 , provided a draft RI and draft FS, both relating to the entire 17 miles of the lower Passaic River, to the EPA on February 18, 2015 and April 30, 2015, respectively. The estimated total cost of the RI/FS is approximately $151 million , which the CPG continues to incur. Of the estimated $151 million , as of August 31, 2015 , the CPG had spent approximately $141 million , of which PSEG's total share was approximately $9 million . The draft FS sets forth various alternatives for remediating the lower Passaic River. The draft FS sets forth the CPG’s estimated costs to remediate the lower 17 miles of the Passaic River which range from approximately $518 million to $3.2 billion . The CPG identified a targeted remedy in the draft FS which would involve removal, treatment and disposal of contaminated sediments taken from targeted locations within the entire 17 miles of the lower Passaic River. The estimated cost in the draft FS for the targeted remedy ranges from approximately $518 million to $772 million . No provisional cost allocation has been made by the CPG for the work contemplated by the draft FS. However, based on (i) the low end of the range of the current estimates of costs to remediate, (ii) PSE&G's and Power's estimates of their share of those costs, and (iii) the continued ability of PSE&G to recover such costs in its rates, PSE&G accrued a $10 million Environmental Costs Liability and a corresponding Regulatory Asset and Power accrued a $3 million Other Noncurrent Liability and a corresponding O&M Expense in the first quarter of 2015. The EPA will consider the comments received on its revised draft FFS and is expected to consider the CPG’s RI/FS prior to issuing a Record of Decision (ROD) of a selected remedy for the lower Passaic River. The EPA has broad authority to implement its selected remedy through the ROD and PSEG cannot at this time predict how the implementation of the ROD might impact PSE&G's and Power's ultimate liability. Until (i) the RI/FS is finalized, (ii) a final remedy is determined by the EPA or through litigation, (iii) PSE&G's and Power’s respective shares of the costs, both in the aggregate as well as individually, are determined, and (iv) PSE&G’s continued ability to recover the costs in its rates is determined, it is not possible to predict this matter’s ultimate impact on our financial statements. It is possible that PSE&G and Power will record additional costs beyond what they have accrued, and that such costs could be material, but PSEG cannot at the current time estimate the amount or range of any additional costs. Natural Resource Damage Claims In 2003, the New Jersey Department of Environmental Protection (NJDEP) directed PSEG, PSE&G and 56 other PRPs to arrange for a natural resource damage assessment and interim compensatory restoration of natural resource injuries along the lower Passaic River and its tributaries pursuant to the New Jersey Spill Compensation and Control Act. The NJDEP alleged that hazardous substances had been discharged from the Essex Site and the Harrison Site. The NJDEP estimated the cost of interim natural resource injury restoration activities along the lower Passaic River at approximately $950 million . In 2007, agencies of the United States Department of Commerce and the United States Department of the Interior (the Passaic River federal trustees) sent letters to PSE&G and other PRPs inviting participation in an assessment of injuries to natural resources that the agencies intended to perform. In 2008, PSEG and a number of other PRPs agreed to share certain immaterial costs the trustees have incurred and will incur going forward, and to work with the trustees to explore whether some or all of the trustees’ claims can be resolved in a cooperative fashion. That effort is continuing. PSE&G and Power are unable to estimate their respective portions of the possible loss or range of loss related to this matter. Newark Bay Study Area The EPA has established the Newark Bay Study Area, which it defines as Newark Bay and portions of the Hackensack River, the Arthur Kill and the Kill Van Kull. In August 2006, the EPA sent PSEG and 11 other entities notices that it considered each of the entities to be a PRP with respect to contamination in the Study Area. The notice letter requested that the PRPs fund an EPA-approved study in the Newark Bay Study Area. The notice stated the EPA’s belief that hazardous substances were released from sites owned by PSEG companies and located on the Hackensack River, including two operating electric generating stations (Hudson and Kearny sites) and one former MGP site. PSEG has participated in and partially funded the second phase of this study. Notices to fund the next phase of the study have been received but PSEG has not consented to fund the third phase. PSE&G and Power are unable to estimate their respective portions of the possible loss or range of loss related to this matter. MGP Remediation Program PSE&G is working with the NJDEP to assess, investigate and remediate environmental conditions at its former MGP sites. To date, 38 sites requiring some level of remedial action have been identified. Based on its current studies, PSE&G has determined that the estimated cost to remediate all MGP sites to completion could range between $450 million and $518 million through 2021, including its $10 million share for the Passaic River as discussed above. Since no amount within the range is considered to be most likely, PSE&G has recorded a liability of $450 million as of September 30, 2015 . Of this amount, $73 million was recorded in Other Current Liabilities and $377 million was reflected as Environmental Costs in Noncurrent Liabilities. PSE&G has recorded a $450 million Regulatory Asset with respect to these costs. PSE&G periodically updates its studies taking into account any new regulations or new information which could impact future remediation costs and adjusts its recorded liability accordingly. Prevention of Significant Deterioration (PSD)/New Source Review (NSR) The PSD/NSR regulations, promulgated under the Clean Air Act (CAA), require major sources of certain air pollutants to obtain permits, install pollution control technology and obtain offsets, in some circumstances, when those sources undergo a “major modification,” as defined in the regulations. The federal government may order companies that are not in compliance with the PSD/NSR regulations to install the best available control technology at the affected plants and to pay monetary penalties ranging from $25,000 to $37,500 per day for each violation, depending upon when the alleged violation occurred. In 2009, the EPA issued a notice of violation to Power and the other owners of the Keystone coal-fired plant in Pennsylvania, alleging, among other things, that various capital improvement projects were completed at the plant which are considered modifications (or major modifications) causing significant net emission increases of PSD/NSR air pollutants, beginning in 1985 for Keystone Unit 1 and in 1984 for Keystone Unit 2. The notice of violation states that none of these modifications underwent the PSD/NSR permitting process prior to being put into service, which the EPA alleges was required under the CAA. The notice of violation states that the EPA may issue an order requiring compliance with the relevant CAA provisions and may seek injunctive relief and/or civil penalties. Power owns approximately 23% of the plant. Power cannot predict the outcome of this matter. Clean Water Act Permit Renewals Pursuant to the Federal Water Pollution Control Act (FWPCA), National Pollutant Discharge Elimination System permits expire within five years of their effective date. In order to renew these permits, but allow a plant to continue to operate, an owner or operator must file a permit application no later than six months prior to expiration of the permit. States with delegated federal authority for this program manage these permits. The New Jersey Department of Environmental Protection (NJDEP) manages the permits under the New Jersey Pollutant Discharge Elimination System (NJPDES) program. Connecticut and New York also have permits to manage their respective pollutant discharge elimination system programs. In 2001, the NJDEP issued a renewed NJPDES permit for Salem, expiring in July 2006, allowing for the continued operation of Salem with its existing cooling water intake system. In February 2006, Power filed with the NJDEP a renewal application allowing Salem to continue operating under its existing NJPDES permit until a new permit is issued. On June 30, 2015, the NJDEP issued a draft Salem permit. The draft permit does not require installation of cooling towers and allows Salem to continue to operate utilizing the existing once-through cooling water system with certain required system modifications. The draft permit was subject to a public notice and comment period. The NJDEP may make revisions before issuing the final permit expected during the first half of 2016. Power participated in the NJDEP’s August 5, 2015 public hearing and submitted comments on the draft permit on September 18, 2015. On May 19, 2014, the EPA issued a final rule that establishes new requirements for the regulation of cooling water intake structures at existing power plants and industrial facilities with a design flow of more than two million gallons of water per day. On August 15, 2014, the EPA established October 14, 2014 as the effective date for each state to implement the provisions of the rule going forward when considering the renewal of permits for existing facilities on a case by case basis. On September 5, 2014, several environmental non-governmental groups and certain energy industry groups filed motions to litigate the provisions of the rule. This case is pending at the U.S. Second Circuit Court of Appeals. In two related actions on October 17, 2014 and November 20, 2014, several environmental non-governmental groups initiated challenges to the endangered species act provisions of the 316 (b) rule. Power is unable to determine the ultimate impact of these actions on the implementation of the rule. State permitting decisions could have a material impact on Power’s ability to renew permits at its larger once-through cooled plants, including Salem, Hudson, Mercer, Bridgeport and possibly Sewaren and New Haven, without making significant upgrades to existing intake structures and cooling systems. The costs of those upgrades to one or more of Power’s once-through cooled plants would be material, and would require economic review to determine whether to continue operations at these facilities. For example, in Power’s application to renew its Salem permit, filed with the NJDEP in February 2006, the estimated costs for adding cooling towers for Salem were approximately $1.0 billion , of which Power’s share would have been approximately $575 million . The filing has not been updated. Currently, potential costs associated with any closed cycle cooling requirements are not included in Power’s forecasted capital expenditures. Power is unable to predict the outcome of these permitting decisions and the effect, if any, that they may have on Power's future capital requirements, financial condition or results of operations. Bridgeport Harbor National Pollutant Discharge Elimination System (NPDES) Permit Compliance In April 2015, Power determined that monitoring and reporting practices related to certain permitted wastewater discharges at its Bridgeport Harbor station may have violated conditions of the station's NPDES permit and applicable regulations and could subject it to fines and penalties. Power has notified the Connecticut Department of Energy and Environmental Protection of the issues and has taken actions to investigate and resolve the potential non-compliance. At this early stage Power cannot predict the impact of this matter. Steam Electric Effluent Guidelines On September 30, 2015, the EPA issued a new Effluent Guidelines Limitation Rule for steam electric generating units. The rule establishes new best available technology economically achievable (BAT) standards for fly ash transport water, bottom ash transport water, flue gas desulfurization and flue gas mercury control wastewater. The EPA provides an implementation period for currently existing discharges of three years or up to eight years if a facility needs more time to implement equipment upgrades and provide supporting information to its permitting authority. In the intervening time period, existing discharge standards continue to apply. Power's Mercer and Bridgeport Harbor stations have bottom ash transport water discharges that are regulated under this rule. Power is unable to predict if these new standards will have a material impact on Power's future capital requirements, financial condition or results of operations. Coal Combustion Residuals (CCRs) On December 19, 2014, the EPA issued a final rule which regulates CCRs as non-hazardous and requires that facility owners implement a series of actions to close or upgrade existing CCR surface impoundments and/or landfills. It also establishes new provisions for the construction of new surface impoundments and landfills. Power's Hudson and Mercer generating stations, along with its co-owned Keystone and Conemaugh stations, are subject to the provisions of this rule. On April 17, 2015, the final rule was published with an effective date of October 19, 2015. Accordingly in June 2015, Power recorded an additional asset retirement obligation to comply with the final CCR rule which was not material to Power’s results of operations, financial condition or cash flows. Basic Generation Service (BGS) and Basic Gas Supply Service (BGSS) PSE&G obtains its electric supply requirements through the annual New Jersey BGS auctions for two categories of customers who choose not to purchase electric supply from third party suppliers. The first category, which represents about 80% of PSE&G's load requirement, are residential and smaller commercial and industrial customers (BGS-Residential Small Commercial Pricing (RSCP)). The second category are larger customers that exceed a BPU-established load (kW) threshold (BGS-Commercial and Industrial Pricing (CIEP)). Pursuant to applicable BPU rules, PSE&G enters into the Supplier Master Agreement with the winners of these BGS auctions following the BPU’s approval of the auction results. PSE&G has entered into contracts with winning BGS suppliers, including Power, to purchase BGS for PSE&G’s load requirements. The winners of the auction (including Power) are responsible for fulfilling all the requirements of a PJM Load Serving Entity including the provision of capacity, energy, ancillary services, transmission and any other services required by PJM. BGS suppliers assume all volume risk and customer migration risk and must satisfy New Jersey’s renewable portfolio standards. The BGS-CIEP auction is for a one-year supply period from June 1 to May 31 with the BGS-CIEP auction price measured in dollars per MW-day for capacity. The final price for the BGS-CIEP auction year commencing June 1, 2015 is $272.78 per MW-day, replacing the BGS-CIEP auction year price ending May 31, 2015 of $282.04 per MW-day. Energy for BGS-CIEP is priced at hourly PJM locational marginal prices for the contract period. PSE&G contracts for its anticipated BGS-RSCP load on a three-year rolling basis, whereby each year one-third of the load is procured for a three-year period. The contract prices in dollars per MWh for the BGS-RSCP supply, as well as the approximate load, are as follows: Auction Year 2012 2013 2014 2015 36-Month Terms Ending May 2015 May 2016 May 2017 May 2018 (A) Load (MW) 2,900 2,800 2,800 2,900 $ per MWh $83.88 $92.18 $97.39 $99.54 (A) Prices set for the 2015 BGS auction year became effective on June 1, 2015 when the 2012 BGS auction agreements expired. Power seeks to mitigate volatility in its results by contracting in advance for the sale of most of its anticipated electric output as well as its anticipated fuel needs. As part of its objective, Power has entered into contracts to directly supply PSE&G and other New Jersey electric distribution companies (EDCs) with a portion of their respective BGS requirements through the New Jersey BGS auction process, described above. PSE&G has a full-requirements contract with Power to meet the gas supply requirements of PSE&G’s gas customers. Power has entered into hedges for a portion of these anticipated BGSS obligations, as permitted by the BPU. The BPU permits PSE&G to recover the cost of gas hedging up to 115 billion cubic feet or 80% of its residential gas supply annual requirements through the BGSS tariff. Current plans call for Power to hedge on behalf of PSE&G approximately 70 billion cubic feet or 50% of its residential gas supply annual requirements. For additional information, see Note 17. Related-Party Transactions . Minimum Fuel Purchase Requirements Power’s nuclear fuel strategy is to maintain certain levels of uranium and to make periodic purchases to support such levels. As such, the commitments referred to in the following table may include estimated quantities to be purchased that deviate from contractual nominal quantities. Power’s nuclear fuel commitments cover approximately 100% of its estimated uranium, enrichment and fabrication requirements through 2017 and a significant portion through 2020 at Salem, Hope Creek and Peach Bottom. Power has various long-term fuel purchase commitments for coal through 2018 to support its fossil generation stations. Power also has various multi-year contracts for natural gas and firm transportation and storage capacity for natural gas that are primarily used to meet its obligations to PSE&G. When there is excess delivery capacity available, Power can use the gas to supply its fossil generating stations. As of September 30, 2015 , the total minimum purchase requirements included in these commitments were as follows: Fuel Type Power's Share of Commitments through 2019 Millions Nuclear Fuel Uranium $ 440 Enrichment $ 345 Fabrication $ 179 Natural Gas $ 1,001 Coal $ 331 Regulatory Proceedings FERC Compliance In the first quarter of 2014, Power discovered that it incorrectly calculated certain components of its cost-based bids for its New Jersey fossil generating units in the PJM energy market. Upon discovery of the errors, PSEG retained outside counsel to assist in the conduct of an investigation into the matter. As the investigation proceeded, additional pricing errors in the bids were identified. It was further determined that the quantity of energy that Power offered into the energy market for its fossil peaking units differed from the amount for which Power was compensated in the capacity market for those units. PSEG informed FERC, PJM and the PJM Independent Market Monitor (IMM) of these additional issues, corrected the identified errors and modified the bid quantities for its peaking units. Power continues to implement procedures to help mitigate the risk of similar issues occurring in the future. On September 2, 2014, FERC Staff initiated a preliminary, non-public staff investigation into the matter. This investigation, which is ongoing, could result in FERC seeking disgorgement of any over-collected amounts, civil penalties and non-financial remedies. During the three months ended March 31, 2014 , based upon its best estimate available at the time, Power recorded a charge to income in the amount of $25 million related to this matter. It is not possible at this time to reasonably estimate the potential range of loss or full impact or predict any resulting penalties or other costs associated with this matter, or the applicability of mitigating factors. As new information becomes available or future developments occur in this investigation, it is possible that Power will record additional estimated losses and such additional losses may be material. New Jersey Clean Energy Program In June 2015, the BPU established the funding level for fiscal year 2016 applicable to its Renewable Energy and Energy Efficiency programs. The fiscal year 2016 aggregate funding for all EDCs is $345 million with PSE&G's share of the funding at $200 million . PSE&G has a current liability of $185 million as of September 30, 2015 for its outstanding share of the fiscal year 2016 and remaining fiscal year 2015 funding, respectively. The liability is reduced as normal payments are made. The liability has been recorded with an offsetting Regulatory Asset, since the costs associated with this program are recovered from PSE&G ratepayers through the Societal Benefits Charge (SBC). Superstorm Sandy In late October 2012, Superstorm Sandy caused severe damage to PSE&G's T&D system throughout its service territory as well as to some of Power's generation infrastructure in the northern part of New Jersey. Strong winds and the resulting storm surge caused damage to switching stations, substations and generating infrastructure. PSEG maintains insurance coverage against loss or damage to plants and certain properties, subject to certain exceptions and limitations, to the extent such property is usually insured and insurance is available at a reasonable cost. In June 2013, PSEG, PSE&G and Power filed suit in New Jersey state court (NJ Court) against its insurance carriers seeking an interpretation that the insurance policies cover their losses resulting from damage caused by Superstorm Sandy's storm surge. As of December 31, 2012, PSE&G had incurred approximately $295 million of costs to restore service to PSE&G's distribution and transmission systems and $5 million to repair its infrastructure and return it to pre-storm conditions. Of the costs incurred, approximately $40 million was recognized in O&M Expense, $75 million was recorded as Property, Plant and Equipment and $180 million was recorded as a Regulatory Asset because such costs were deferred as approved by the BPU under an Order received in December 2012. Of the $295 million , $36 million related to insured property. In 2012, PSE&G recognized $6 million of insurance recoveries, which were deferred. There were no s |
Power [Member] | |
Loss Contingencies [Line Items] | |
Commitments and Contingent Liabilities | Commitments and Contingent Liabilities Guaranteed Obligations Power’s activities primarily involve the purchase and sale of energy and related products under transportation, physical, financial and forward contracts at fixed and variable prices. These transactions are with numerous counterparties and brokers that may require cash, cash-related instruments or guarantees. Power has unconditionally guaranteed payments to counterparties by its subsidiaries in commodity-related transactions in order to • support current exposure, interest and other costs on sums due and payable in the ordinary course of business, and • obtain credit. Under these agreements, guarantees cover lines of credit between entities and are often reciprocal in nature. The exposure between counterparties can move in either direction. In order for Power to incur a liability for the face value of the outstanding guarantees, its subsidiaries would have to • fully utilize the credit granted to them by every counterparty to whom Power has provided a guarantee, and • all of the related contracts would have to be “out-of-the-money” (if the contracts are terminated, Power would owe money to the counterparties). Power believes the probability of this result is unlikely. For this reason, Power believes that the current exposure at any point in time is a more meaningful representation of the potential liability under these guarantees. This current exposure consists of the net of accounts receivable and accounts payable and the forward value on open positions, less any collateral posted. Power is subject to • counterparty collateral calls related to commodity contracts, and • certain creditworthiness standards as guarantor under performance guarantees of its subsidiaries. Changes in commodity prices can have a material impact on collateral requirements under such contracts, which are posted and received primarily in the form of cash and letters of credit. Power also routinely enters into futures and options transactions for electricity and natural gas as part of its operations. These futures contracts usually require a cash margin deposit with brokers, which can change based on market movement and in accordance with exchange rules. In addition to the guarantees discussed above, Power has also provided payment guarantees to third parties on behalf of its affiliated companies. These guarantees support various other non-commodity related contractual obligations. The face value of Power's outstanding guarantees, current exposure and margin positions as of September 30, 2015 and December 31, 2014 are shown as follows: As of As of September 30, December 31, Millions Face Value of Outstanding Guarantees $ 1,733 $ 1,814 Exposure under Current Guarantees $ 184 $ 273 Letters of Credit Margin Posted $ 178 $ 159 Letters of Credit Margin Received $ 80 $ 40 Cash Deposited and Received: Counterparty Cash Margin Deposited $ — $ — Counterparty Cash Margin Received $ (44 ) $ (13 ) Net Broker Balance Deposited (Received) $ 4 $ 115 In the Event Power were to Lose its Investment Grade Rating: Additional Collateral that could be Required $ 796 $ 945 Liquidity Available under PSEG’s and Power’s Credit Facilities to Post Collateral $ 3,375 $ 3,495 Additional Amounts Posted: Other Letters of Credit $ 47 $ 45 As part of determining credit exposure, Power nets receivables and payables with the corresponding net energy contract balances. See Note 10. Financial Risk Management Activities for further discussion. In accordance with PSEG's accounting policy, where it is applicable, cash (received)/deposited is allocated against derivative asset and liability positions with the same counterparty on the face of the Balance Sheet. The remaining balances of net cash (received)/deposited after allocation are generally included in Accounts Payable and Receivable, respectively. In the event of a deterioration of Power’s credit rating to below investment grade, which would represent a three level downgrade from its current S&P and Moody’s ratings, many of these agreements allow the counterparty to demand further performance assurance. See table above. In addition to amounts for outstanding guarantees, current exposure and margin positions, PSEG and Power had posted letters of credit to support Power's various other non-energy contractual and environmental obligations. See preceding table. PSEG had also issued a $106 million guarantee to support Power's payment obligations related to its equity interest in the PennEast natural gas pipeline and a $21 million guarantee to support Power's payment obligations related to construction of a 755 MW gas-fired combined cycle generating station in Maryland. In the event that PSEG were to be downgraded to below investment grade and failed to meet minimum net worth requirements, these guarantees would each have to be replaced by a letter of credit. Environmental Matters Passaic River Historic operations of PSEG companies and the operations of hundreds of other companies along the Passaic and Hackensack Rivers are alleged by Federal and State agencies to have discharged substantial contamination into the Passaic River/Newark Bay Complex in violation of various statutes as discussed as follows. Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 (CERCLA) In 2002, the U.S. Environmental Protection Agency (EPA) determined that a 17 -mile stretch of the lower Passaic River from Newark to Clifton, New Jersey is a “Superfund” site under CERCLA. This designation allows the EPA to clean up such sites and to compel responsible parties to perform cleanups or reimburse the government for cleanups led by the EPA. The EPA further determined that there was a need to perform a comprehensive study of the entire 17 -miles of the lower Passaic River. PSE&G and certain of its predecessors conducted operations at properties in this area of the Passaic River. The properties included one operating electric generating station (Essex Site), which was transferred to Power, one former generating station and four former manufactured gas plant (MGP) sites. In early 2007, 73 Potentially Responsible Parties (PRPs), including PSE&G and Power, formed a Cooperating Parties Group (CPG) and agreed to assume responsibility for conducting a Remedial Investigation and Feasibility Study (RI/FS) of the 17 miles of the lower Passaic River. At such time, the CPG also agreed to allocate, on an interim basis, the associated costs of the RI/FS among its members on the basis of a mutually agreed upon formula. For the purpose of this interim allocation, which has been revised as parties have exited the CPG, approximately seven percent of the RI/FS costs are currently deemed attributable to PSE&G’s former MGP sites and approximately one percent is attributable to Power’s generating stations. These interim allocations are not binding on PSE&G or Power in terms of their respective shares of the costs that will be ultimately required to remediate the 17 miles of the lower Passaic River. PSEG has provided notice to insurers concerning this potential claim. In June 2008, the EPA and Tierra Solutions, Inc. (Tierra) and Maxus Energy Corporation (Maxus) entered into an early action agreement whereby Tierra/Maxus agreed to remove a portion of the heavily dioxin-contaminated sediment located in the lower Passaic River. The portion of the Passaic River identified in this agreement was located immediately adjacent to Tierra/Maxus’ predecessor company’s (Diamond Shamrock) facility. Pursuant to the agreement between the EPA and Tierra/Maxus, the estimated cost for the work to remove the sediment in this location was $80 million . Phase I of the removal work has been completed. Pursuant to this agreement, Tierra/Maxus have reserved their rights to seek contribution for these removal costs from the other PRPs, including Power and PSE&G. This agreement and the work undertaken pursuant to the action agreement will not affect the ultimate remedy that the EPA will select for the remediation of the 17-mile stretch of the lower Passaic River. In 2012, Tierra/Maxus withdrew from the CPG and refused to participate as members going forward, other than with respect to their obligation to fund the EPA’s portion of its RI/FS oversight costs. At such time, the remaining members of the CPG, in agreement with the EPA, commenced the removal of certain contaminated sediments at Passaic River Mile 10.9 at an estimated cost of $25 million to $30 million . PSEG’s share of the cost of that effort is approximately three percent . The remaining CPG members have reserved their rights to seek reimbursement from Tierra/Maxus for the costs of the River Mile 10.9 removal. On April 11, 2014, the EPA released its revised draft “Focused Feasibility Study” (FFS) which contemplates the removal of 4.3 million cubic yards of sediment from the bottom of the lower eight miles of the 17-mile stretch of the Passaic River. The revised draft FFS sets forth various alternatives for remediating this portion of the Passaic River. The EPA’s estimated costs to remediate the lower eight miles of the Passaic River range from $365 million for a targeted remedy to $3.3 billion for a deep dredge of this portion of the Passaic River. The EPA also identified in the revised draft FFS its preferred alternative, which would involve dredging the lower eight miles of the river bank-to-bank and installing an engineered cap. The estimated cost in the revised draft FFS for the EPA's preferred alternative is $1.7 billion . No provisional cost allocation has been made by the CPG for the work contemplated by the revised draft FFS, and the work contemplated by the revised draft FFS is not subject to the CPG’s cost sharing allocation agreed to in connection with the removal work for River Mile 10.9 or in connection with the conduct of the RI/FS. The revised draft FFS was subject to a public comment period, and remains subject to the EPA’s response to comments submitted, a design phase and at least an estimated five years for completion of the work. The public comment period for the revised draft FFS closed on August 21, 2014. Over 300 comments were submitted by a variety of entities potentially impacted by the revised draft FFS, including the CPG, individual companies, municipalities, public officials, citizens groups, Amtrak, NJ Transit and others. The CPG, which consisted of 60 members as of September 30, 2015 , provided a draft RI and draft FS, both relating to the entire 17 miles of the lower Passaic River, to the EPA on February 18, 2015 and April 30, 2015, respectively. The estimated total cost of the RI/FS is approximately $151 million , which the CPG continues to incur. Of the estimated $151 million , as of August 31, 2015 , the CPG had spent approximately $141 million , of which PSEG's total share was approximately $9 million . The draft FS sets forth various alternatives for remediating the lower Passaic River. The draft FS sets forth the CPG’s estimated costs to remediate the lower 17 miles of the Passaic River which range from approximately $518 million to $3.2 billion . The CPG identified a targeted remedy in the draft FS which would involve removal, treatment and disposal of contaminated sediments taken from targeted locations within the entire 17 miles of the lower Passaic River. The estimated cost in the draft FS for the targeted remedy ranges from approximately $518 million to $772 million . No provisional cost allocation has been made by the CPG for the work contemplated by the draft FS. However, based on (i) the low end of the range of the current estimates of costs to remediate, (ii) PSE&G's and Power's estimates of their share of those costs, and (iii) the continued ability of PSE&G to recover such costs in its rates, PSE&G accrued a $10 million Environmental Costs Liability and a corresponding Regulatory Asset and Power accrued a $3 million Other Noncurrent Liability and a corresponding O&M Expense in the first quarter of 2015. The EPA will consider the comments received on its revised draft FFS and is expected to consider the CPG’s RI/FS prior to issuing a Record of Decision (ROD) of a selected remedy for the lower Passaic River. The EPA has broad authority to implement its selected remedy through the ROD and PSEG cannot at this time predict how the implementation of the ROD might impact PSE&G's and Power's ultimate liability. Until (i) the RI/FS is finalized, (ii) a final remedy is determined by the EPA or through litigation, (iii) PSE&G's and Power’s respective shares of the costs, both in the aggregate as well as individually, are determined, and (iv) PSE&G’s continued ability to recover the costs in its rates is determined, it is not possible to predict this matter’s ultimate impact on our financial statements. It is possible that PSE&G and Power will record additional costs beyond what they have accrued, and that such costs could be material, but PSEG cannot at the current time estimate the amount or range of any additional costs. Natural Resource Damage Claims In 2003, the New Jersey Department of Environmental Protection (NJDEP) directed PSEG, PSE&G and 56 other PRPs to arrange for a natural resource damage assessment and interim compensatory restoration of natural resource injuries along the lower Passaic River and its tributaries pursuant to the New Jersey Spill Compensation and Control Act. The NJDEP alleged that hazardous substances had been discharged from the Essex Site and the Harrison Site. The NJDEP estimated the cost of interim natural resource injury restoration activities along the lower Passaic River at approximately $950 million . In 2007, agencies of the United States Department of Commerce and the United States Department of the Interior (the Passaic River federal trustees) sent letters to PSE&G and other PRPs inviting participation in an assessment of injuries to natural resources that the agencies intended to perform. In 2008, PSEG and a number of other PRPs agreed to share certain immaterial costs the trustees have incurred and will incur going forward, and to work with the trustees to explore whether some or all of the trustees’ claims can be resolved in a cooperative fashion. That effort is continuing. PSE&G and Power are unable to estimate their respective portions of the possible loss or range of loss related to this matter. Newark Bay Study Area The EPA has established the Newark Bay Study Area, which it defines as Newark Bay and portions of the Hackensack River, the Arthur Kill and the Kill Van Kull. In August 2006, the EPA sent PSEG and 11 other entities notices that it considered each of the entities to be a PRP with respect to contamination in the Study Area. The notice letter requested that the PRPs fund an EPA-approved study in the Newark Bay Study Area. The notice stated the EPA’s belief that hazardous substances were released from sites owned by PSEG companies and located on the Hackensack River, including two operating electric generating stations (Hudson and Kearny sites) and one former MGP site. PSEG has participated in and partially funded the second phase of this study. Notices to fund the next phase of the study have been received but PSEG has not consented to fund the third phase. PSE&G and Power are unable to estimate their respective portions of the possible loss or range of loss related to this matter. MGP Remediation Program PSE&G is working with the NJDEP to assess, investigate and remediate environmental conditions at its former MGP sites. To date, 38 sites requiring some level of remedial action have been identified. Based on its current studies, PSE&G has determined that the estimated cost to remediate all MGP sites to completion could range between $450 million and $518 million through 2021, including its $10 million share for the Passaic River as discussed above. Since no amount within the range is considered to be most likely, PSE&G has recorded a liability of $450 million as of September 30, 2015 . Of this amount, $73 million was recorded in Other Current Liabilities and $377 million was reflected as Environmental Costs in Noncurrent Liabilities. PSE&G has recorded a $450 million Regulatory Asset with respect to these costs. PSE&G periodically updates its studies taking into account any new regulations or new information which could impact future remediation costs and adjusts its recorded liability accordingly. Prevention of Significant Deterioration (PSD)/New Source Review (NSR) The PSD/NSR regulations, promulgated under the Clean Air Act (CAA), require major sources of certain air pollutants to obtain permits, install pollution control technology and obtain offsets, in some circumstances, when those sources undergo a “major modification,” as defined in the regulations. The federal government may order companies that are not in compliance with the PSD/NSR regulations to install the best available control technology at the affected plants and to pay monetary penalties ranging from $25,000 to $37,500 per day for each violation, depending upon when the alleged violation occurred. In 2009, the EPA issued a notice of violation to Power and the other owners of the Keystone coal-fired plant in Pennsylvania, alleging, among other things, that various capital improvement projects were completed at the plant which are considered modifications (or major modifications) causing significant net emission increases of PSD/NSR air pollutants, beginning in 1985 for Keystone Unit 1 and in 1984 for Keystone Unit 2. The notice of violation states that none of these modifications underwent the PSD/NSR permitting process prior to being put into service, which the EPA alleges was required under the CAA. The notice of violation states that the EPA may issue an order requiring compliance with the relevant CAA provisions and may seek injunctive relief and/or civil penalties. Power owns approximately 23% of the plant. Power cannot predict the outcome of this matter. Clean Water Act Permit Renewals Pursuant to the Federal Water Pollution Control Act (FWPCA), National Pollutant Discharge Elimination System permits expire within five years of their effective date. In order to renew these permits, but allow a plant to continue to operate, an owner or operator must file a permit application no later than six months prior to expiration of the permit. States with delegated federal authority for this program manage these permits. The New Jersey Department of Environmental Protection (NJDEP) manages the permits under the New Jersey Pollutant Discharge Elimination System (NJPDES) program. Connecticut and New York also have permits to manage their respective pollutant discharge elimination system programs. In 2001, the NJDEP issued a renewed NJPDES permit for Salem, expiring in July 2006, allowing for the continued operation of Salem with its existing cooling water intake system. In February 2006, Power filed with the NJDEP a renewal application allowing Salem to continue operating under its existing NJPDES permit until a new permit is issued. On June 30, 2015, the NJDEP issued a draft Salem permit. The draft permit does not require installation of cooling towers and allows Salem to continue to operate utilizing the existing once-through cooling water system with certain required system modifications. The draft permit was subject to a public notice and comment period. The NJDEP may make revisions before issuing the final permit expected during the first half of 2016. Power participated in the NJDEP’s August 5, 2015 public hearing and submitted comments on the draft permit on September 18, 2015. On May 19, 2014, the EPA issued a final rule that establishes new requirements for the regulation of cooling water intake structures at existing power plants and industrial facilities with a design flow of more than two million gallons of water per day. On August 15, 2014, the EPA established October 14, 2014 as the effective date for each state to implement the provisions of the rule going forward when considering the renewal of permits for existing facilities on a case by case basis. On September 5, 2014, several environmental non-governmental groups and certain energy industry groups filed motions to litigate the provisions of the rule. This case is pending at the U.S. Second Circuit Court of Appeals. In two related actions on October 17, 2014 and November 20, 2014, several environmental non-governmental groups initiated challenges to the endangered species act provisions of the 316 (b) rule. Power is unable to determine the ultimate impact of these actions on the implementation of the rule. State permitting decisions could have a material impact on Power’s ability to renew permits at its larger once-through cooled plants, including Salem, Hudson, Mercer, Bridgeport and possibly Sewaren and New Haven, without making significant upgrades to existing intake structures and cooling systems. The costs of those upgrades to one or more of Power’s once-through cooled plants would be material, and would require economic review to determine whether to continue operations at these facilities. For example, in Power’s application to renew its Salem permit, filed with the NJDEP in February 2006, the estimated costs for adding cooling towers for Salem were approximately $1.0 billion , of which Power’s share would have been approximately $575 million . The filing has not been updated. Currently, potential costs associated with any closed cycle cooling requirements are not included in Power’s forecasted capital expenditures. Power is unable to predict the outcome of these permitting decisions and the effect, if any, that they may have on Power's future capital requirements, financial condition or results of operations. Bridgeport Harbor National Pollutant Discharge Elimination System (NPDES) Permit Compliance In April 2015, Power determined that monitoring and reporting practices related to certain permitted wastewater discharges at its Bridgeport Harbor station may have violated conditions of the station's NPDES permit and applicable regulations and could subject it to fines and penalties. Power has notified the Connecticut Department of Energy and Environmental Protection of the issues and has taken actions to investigate and resolve the potential non-compliance. At this early stage Power cannot predict the impact of this matter. Steam Electric Effluent Guidelines On September 30, 2015, the EPA issued a new Effluent Guidelines Limitation Rule for steam electric generating units. The rule establishes new best available technology economically achievable (BAT) standards for fly ash transport water, bottom ash transport water, flue gas desulfurization and flue gas mercury control wastewater. The EPA provides an implementation period for currently existing discharges of three years or up to eight years if a facility needs more time to implement equipment upgrades and provide supporting information to its permitting authority. In the intervening time period, existing discharge standards continue to apply. Power's Mercer and Bridgeport Harbor stations have bottom ash transport water discharges that are regulated under this rule. Power is unable to predict if these new standards will have a material impact on Power's future capital requirements, financial condition or results of operations. Coal Combustion Residuals (CCRs) On December 19, 2014, the EPA issued a final rule which regulates CCRs as non-hazardous and requires that facility owners implement a series of actions to close or upgrade existing CCR surface impoundments and/or landfills. It also establishes new provisions for the construction of new surface impoundments and landfills. Power's Hudson and Mercer generating stations, along with its co-owned Keystone and Conemaugh stations, are subject to the provisions of this rule. On April 17, 2015, the final rule was published with an effective date of October 19, 2015. Accordingly in June 2015, Power recorded an additional asset retirement obligation to comply with the final CCR rule which was not material to Power’s results of operations, financial condition or cash flows. Basic Generation Service (BGS) and Basic Gas Supply Service (BGSS) PSE&G obtains its electric supply requirements through the annual New Jersey BGS auctions for two categories of customers who choose not to purchase electric supply from third party suppliers. The first category, which represents about 80% of PSE&G's load requirement, are residential and smaller commercial and industrial customers (BGS-Residential Small Commercial Pricing (RSCP)). The second category are larger customers that exceed a BPU-established load (kW) threshold (BGS-Commercial and Industrial Pricing (CIEP)). Pursuant to applicable BPU rules, PSE&G enters into the Supplier Master Agreement with the winners of these BGS auctions following the BPU’s approval of the auction results. PSE&G has entered into contracts with winning BGS suppliers, including Power, to purchase BGS for PSE&G’s load requirements. The winners of the auction (including Power) are responsible for fulfilling all the requirements of a PJM Load Serving Entity including the provision of capacity, energy, ancillary services, transmission and any other services required by PJM. BGS suppliers assume all volume risk and customer migration risk and must satisfy New Jersey’s renewable portfolio standards. The BGS-CIEP auction is for a one-year supply period from June 1 to May 31 with the BGS-CIEP auction price measured in dollars per MW-day for capacity. The final price for the BGS-CIEP auction year commencing June 1, 2015 is $272.78 per MW-day, replacing the BGS-CIEP auction year price ending May 31, 2015 of $282.04 per MW-day. Energy for BGS-CIEP is priced at hourly PJM locational marginal prices for the contract period. PSE&G contracts for its anticipated BGS-RSCP load on a three-year rolling basis, whereby each year one-third of the load is procured for a three-year period. The contract prices in dollars per MWh for the BGS-RSCP supply, as well as the approximate load, are as follows: Auction Year 2012 2013 2014 2015 36-Month Terms Ending May 2015 May 2016 May 2017 May 2018 (A) Load (MW) 2,900 2,800 2,800 2,900 $ per MWh $83.88 $92.18 $97.39 $99.54 (A) Prices set for the 2015 BGS auction year became effective on June 1, 2015 when the 2012 BGS auction agreements expired. Power seeks to mitigate volatility in its results by contracting in advance for the sale of most of its anticipated electric output as well as its anticipated fuel needs. As part of its objective, Power has entered into contracts to directly supply PSE&G and other New Jersey electric distribution companies (EDCs) with a portion of their respective BGS requirements through the New Jersey BGS auction process, described above. PSE&G has a full-requirements contract with Power to meet the gas supply requirements of PSE&G’s gas customers. Power has entered into hedges for a portion of these anticipated BGSS obligations, as permitted by the BPU. The BPU permits PSE&G to recover the cost of gas hedging up to 115 billion cubic feet or 80% of its residential gas supply annual requirements through the BGSS tariff. Current plans call for Power to hedge on behalf of PSE&G approximately 70 billion cubic feet or 50% of its residential gas supply annual requirements. For additional information, see Note 17. Related-Party Transactions . Minimum Fuel Purchase Requirements Power’s nuclear fuel strategy is to maintain certain levels of uranium and to make periodic purchases to support such levels. As such, the commitments referred to in the following table may include estimated quantities to be purchased that deviate from contractual nominal quantities. Power’s nuclear fuel commitments cover approximately 100% of its estimated uranium, enrichment and fabrication requirements through 2017 and a significant portion through 2020 at Salem, Hope Creek and Peach Bottom. Power has various long-term fuel purchase commitments for coal through 2018 to support its fossil generation stations. Power also has various multi-year contracts for natural gas and firm transportation and storage capacity for natural gas that are primarily used to meet its obligations to PSE&G. When there is excess delivery capacity available, Power can use the gas to supply its fossil generating stations. As of September 30, 2015 , the total minimum purchase requirements included in these commitments were as follows: Fuel Type Power's Share of Commitments through 2019 Millions Nuclear Fuel Uranium $ 440 Enrichment $ 345 Fabrication $ 179 Natural Gas $ 1,001 Coal $ 331 Regulatory Proceedings FERC Compliance In the first quarter of 2014, Power discovered that it incorrectly calculated certain components of its cost-based bids for its New Jersey fossil generating units in the PJM energy market. Upon discovery of the errors, PSEG retained outside counsel to assist in the conduct of an investigation into the matter. As the investigation proceeded, additional pricing errors in the bids were identified. It was further determined that the quantity of energy that Power offered into the energy market for its fossil peaking units differed from the amount for which Power was compensated in the capacity market for those units. PSEG informed FERC, PJM and the PJM Independent Market Monitor (IMM) of these additional issues, corrected the identified errors and modified the bid quantities for its peaking units. Power continues to implement procedures to help mitigate the risk of similar issues occurring in the future. On September 2, 2014, FERC Staff initiated a preliminary, non-public staff investigation into the matter. This investigation, which is ongoing, could result in FERC seeking disgorgement of any over-collected amounts, civil penalties and non-financial remedies. During the three months ended March 31, 2014 , based upon its best estimate available at the time, Power recorded a charge to income in the amount of $25 million related to this matter. It is not possible at this time to reasonably estimate the potential range of loss or full impact or predict any resulting penalties or other costs associated with this matter, or the applicability of mitigating factors. As new information becomes available or future developments occur in this investigation, it is possible that Power will record additional estimated losses and such additional losses may be material. New Jersey Clean Energy Program In June 2015, the BPU established the funding level for fiscal year 2016 applicable to its Renewable Energy and Energy Efficiency programs. The fiscal year 2016 aggregate funding for all EDCs is $345 million with PSE&G's share of the funding at $200 million . PSE&G has a current liability of $185 million as of September 30, 2015 for its outstanding share of the fiscal year 2016 and remaining fiscal year 2015 funding, respectively. The liability is reduced as normal payments are made. The liability has been recorded with an offsetting Regulatory Asset, since the costs associated with this program are recovered from PSE&G ratepayers through the Societal Benefits Charge (SBC). Superstorm Sandy In late October 2012, Superstorm Sandy caused severe damage to PSE&G's T&D system throughout its service territory as well as to some of Power's generation infrastructure in the northern part of New Jersey. Strong winds and the resulting storm surge caused damage to switching stations, substations and generating infrastructure. PSEG maintains insurance coverage against loss or damage to plants and certain properties, subject to certain exceptions and limitations, to the extent such property is usually insured and insurance is available at a reasonable cost. In June 2013, PSEG, PSE&G and Power filed suit in New Jersey state court (NJ Court) against its insurance carriers seeking an interpretation that the insurance policies cover their losses resulting from damage caused by Superstorm Sandy's storm surge. As of December 31, 2012, PSE&G had incurred approximately $295 million of costs to restore service to PSE&G's distribution and transmission systems and $5 million to repair its infrastructure and return it to pre-storm conditions. Of the costs incurred, approximately $40 million was recognized in O&M Expense, $75 million was recorded as Property, Plant and Equipment and $180 million was recorded as a Regulatory Asset because such costs were deferred as approved by the BPU under an Order received in December 2012. Of the $295 million , $36 million related to insured property. In 2012, PSE&G recognized $6 million of insurance recoveries, which were deferred. There were no s |
Changes in Capitalization
Changes in Capitalization | 9 Months Ended |
Sep. 30, 2015 | |
Debt Instrument [Line Items] | |
Changes in Capitalization | Changes in Capitalization The following capital transactions occurred in the nine months ended September 30, 2015 : PSE&G • issued $350 million of 3.00% Secured Medium-Term Notes, Series K due May 2025 , • issued $250 million of 4.05% Secured Medium-Term Notes, Series K due May 2045 , • paid $300 million of 2.70% Secured Medium-Term Notes at maturity, • paid $183 million of Transition Funding's securitization debt, and • paid the final $8 million of Transition Funding II's securitization debt. Power • paid cash dividends of $400 million to PSEG. |
PSE And G [Member] | |
Debt Instrument [Line Items] | |
Changes in Capitalization | Changes in Capitalization The following capital transactions occurred in the nine months ended September 30, 2015 : PSE&G • issued $350 million of 3.00% Secured Medium-Term Notes, Series K due May 2025 , • issued $250 million of 4.05% Secured Medium-Term Notes, Series K due May 2045 , • paid $300 million of 2.70% Secured Medium-Term Notes at maturity, • paid $183 million of Transition Funding's securitization debt, and • paid the final $8 million of Transition Funding II's securitization debt. Power • paid cash dividends of $400 million to PSEG. |
Power [Member] | |
Debt Instrument [Line Items] | |
Changes in Capitalization | Changes in Capitalization The following capital transactions occurred in the nine months ended September 30, 2015 : PSE&G • issued $350 million of 3.00% Secured Medium-Term Notes, Series K due May 2025 , • issued $250 million of 4.05% Secured Medium-Term Notes, Series K due May 2045 , • paid $300 million of 2.70% Secured Medium-Term Notes at maturity, • paid $183 million of Transition Funding's securitization debt, and • paid the final $8 million of Transition Funding II's securitization debt. Power • paid cash dividends of $400 million to PSEG. |
Financial Risk Management Activ
Financial Risk Management Activities | 9 Months Ended |
Sep. 30, 2015 | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Financial Risk Management Activities | Financial Risk Management Activities The operations of PSEG, Power and PSE&G are exposed to market risks from changes in commodity prices, interest rates and equity prices that could affect their results of operations and financial condition. Exposure to these risks is managed through normal operating and financing activities and, when appropriate, through hedging transactions. Hedging transactions use derivative instruments to create a relationship in which changes to the value of the assets, liabilities or anticipated transactions exposed to market risks are expected to be offset by changes in the value of these derivative instruments. Derivative accounting guidance requires that a derivative instrument be recognized as either an asset or a liability at fair value, with changes in fair value of the derivative recognized in earnings each period. Other accounting treatments are available through special election and designation provided that the derivative instrument meets specific, restrictive criteria, both at the time of designation and on an ongoing basis. These alternative permissible treatments include normal purchase normal sale (NPNS), cash flow hedge and fair value hedge accounting. PSEG, Power and PSE&G have applied the NPNS scope exception to certain derivative contracts for the forward sale of generation, power procurement agreements and fuel agreements. Transactions receiving NPNS treatment are accounted for upon settlement. For a derivative instrument that qualifies and is designated as a cash flow hedge, the changes in the fair value of such a derivative that are highly effective are recorded in Accumulated Other Comprehensive Income (Loss) until earnings are affected by the variability of cash flows of the hedged transaction. For a derivative instrument that qualifies and is designated as a fair value hedge, the gains or losses on the derivative as well as the offsetting losses or gains on the hedged item attributable to the hedged risk are recognized in earnings each period. Power and PSE&G enter into additional contracts that are derivatives, but do not qualify for or are not designated as either cash flow hedges or fair value hedges. These transactions are economic hedges and changes in the fair value of these contracts are recorded in earnings each period. Commodity Prices Within PSEG and its affiliate companies, Power has the most exposure to commodity price risk. Power is exposed to commodity price risk primarily relating to changes in the market price of electricity, fossil fuels and other commodities. Fluctuations in market prices result from changes in supply and demand, fuel costs, market conditions, weather, state and federal regulatory policies, environmental policies, transmission availability and other factors. Power uses a variety of derivative and non-derivative instruments to manage the commodity price risk of its electric generation facilities, including physical and financial transactions in the wholesale energy markets to mitigate the effects of adverse movements in fuel and electricity prices. The fair value for the majority of these contracts is obtained from quoted market sources. Modeling techniques using assumptions reflective of current market rates, yield curves and forward prices are used to interpolate certain prices when no quoted market exists. Cash Flow Hedges PSEG and Power use forward sale contracts, swaps and futures contracts to hedge certain forecasted natural gas sales made to support the BGSS contract with PSE&G. These derivative transactions qualify and are designated as cash flow hedges. As of September 30, 2015 and December 31, 2014 , the fair value and the impact on Accumulated Other Comprehensive Income (Loss) associated with accounting hedge activity were as follows: As of As of September 30, December 31, Millions Fair Value of Cash Flow Hedges $ 2 $ 18 Impact on Accumulated Other Comprehensive Income (Loss) (after tax) $ 1 $ 10 The expiration date of the longest-dated cash flow hedge at Power is in December 2015 . Power’s remaining $1 million of after-tax unrealized gains on these derivatives is expected to be reclassified to earnings during the next 12 months. There was no ineffectiveness associated with qualifying hedges as of September 30, 2015 . Economic Hedges Power enters into derivative contracts that do not qualify or are not designated as either cash flow or fair value hedges. Power enters into financial options, futures, swaps, fuel purchases and forward purchases and sales of electricity. These transactions are economic hedges, intended to mitigate exposure to fluctuations in commodity prices and optimize the value of Power's expected generation. Changes in the fair market value of these contracts are recorded in earnings. PSE&G is a party to certain long-term natural gas sales derivative contracts to optimize its pipeline capacity utilization. Changes in the fair market value of these contracts are recorded in Regulatory Assets and Regulatory Liabilities. Interest Rates PSEG, Power and PSE&G are subject to the risk of fluctuating interest rates in the normal course of business. Exposure to this risk is managed by targeting a balanced debt maturity profile which limits refinancing in any given period or interest rate environment. In addition, they have used a mix of fixed and floating rate debt and interest rate swaps. Fair Value Hedges PSEG enters into fair value hedges to convert fixed-rate debt into variable-rate debt. As of September 30, 2015 , PSEG had interest rate swaps outstanding totaling $850 million . These swaps convert Power’s $300 million of 5.5% Senior Notes due December 2015, $300 million of Power’s $303 million of 5.32% Senior Notes due September 2016 and Power’s $250 million of 2.75% Senior Notes due September 2016 into variable-rate debt. These interest rate swaps are designated and effective as fair value hedges. The fair value changes of the interest rate swaps are fully offset by the changes in the fair value of the underlying forecasted interest payments of the debt. As of September 30, 2015 and December 31, 2014 , the fair value of all the underlying hedges was $11 million and $22 million , respectively. Cash Flow Hedges PSEG uses interest rate swaps and other derivatives, which are designated and effective as cash flow hedges, to manage its exposure to the variability of cash flows, primarily related to variable-rate debt instruments. The Accumulated Other Comprehensive Income (Loss) (after tax) related to interest rate derivatives designated as cash flow hedges was immaterial as of September 30, 2015 and December 31, 2014 , respectively. Fair Values of Derivative Instruments The following are the fair values of derivative instruments on the Condensed Consolidated Balance Sheets. The following tables also include disclosures for offsetting derivative assets and liabilities which are subject to a master netting or similar agreement. In general, the terms of the agreements provide that in the event of an early termination the counterparties have the right to offset amounts owed or owing under that and any other agreement with the same counterparty. Accordingly, and in accordance with our accounting policy, these positions have been offset on the Condensed Consolidated Balance Sheets of Power, PSE&G and PSEG. The following tabular disclosure does not include the offsetting of trade receivables and payables. As of September 30, 2015 Power (A) PSE&G (A) PSEG (A) Consolidated Cash Flow Hedges Not Designated Not Designated Fair Value Hedges Balance Sheet Location Energy- Related Contracts Energy- Related Contracts Netting (B) Total Power Energy- Related Contracts Interest Rate Swaps Total Derivatives Millions Derivative Contracts Current Assets $ 2 $ 413 $ (268 ) $ 147 $ 4 $ 11 $ 162 Noncurrent Assets — 284 (193 ) 91 — — 91 Total Mark-to-Market Derivative Assets $ 2 $ 697 $ (461 ) $ 238 $ 4 $ 11 $ 253 Derivative Contracts Current Liabilities $ — $ (311 ) $ 241 $ (70 ) $ — $ — $ (70 ) Noncurrent Liabilities — (178 ) 162 (16 ) (7 ) — (23 ) Total Mark-to-Market Derivative (Liabilities) $ — $ (489 ) $ 403 $ (86 ) $ (7 ) $ — $ (93 ) Total Net Mark-to-Market Derivative Assets (Liabilities) $ 2 $ 208 $ (58 ) $ 152 $ (3 ) $ 11 $ 160 As of December 31, 2014 Power (A) PSE&G (A) PSEG (A) Consolidated Cash Flow Hedges Not Designated Not Designated Fair Value Hedges Balance Sheet Location Energy- Related Contracts Energy- Related Contracts Netting (B) Total Power Energy- Related Contracts Interest Rate Swaps Total Derivatives Millions Derivative Contracts Current Assets $ 18 $ 597 $ (408 ) $ 207 $ 18 $ 15 $ 240 Noncurrent Assets — 171 (109 ) 62 8 7 77 Total Mark-to-Market Derivative Assets $ 18 $ 768 $ (517 ) $ 269 $ 26 $ 22 $ 317 Derivative Contracts Current Liabilities $ — $ (568 ) $ 436 $ (132 ) $ — $ — $ (132 ) Noncurrent Liabilities — (138 ) 105 (33 ) — — (33 ) Total Mark-to-Market Derivative (Liabilities) $ — $ (706 ) $ 541 $ (165 ) $ — $ — $ (165 ) Total Net Mark-to-Market Derivative Assets (Liabilities) $ 18 $ 62 $ 24 $ 104 $ 26 $ 22 $ 152 (A) Substantially all of Power's and PSEG's derivative instruments are contracts subject to master netting agreements. Contracts not subject to master netting or similar agreements are immaterial and did not have any collateral posted or received as of September 30, 2015 and December 31, 2014 . PSE&G does not have any derivative contracts subject to master netting or similar agreements. (B) Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral received or posted that has been allocated to derivative positions, where the right of offset exists, has been offset on the Condensed Consolidated Balance Sheets. As of September 30, 2015 and December 31, 2014 , net cash collateral (received) paid of $(58) million and $24 million , respectively, were netted against the corresponding net derivative contract positions. Of the $(58) million as of September 30, 2015 , $(32) million and $(38) million of cash collateral were netted against current assets and noncurrent assets, respectively, and $5 million and $7 million were netted against current liabilities and noncurrent liabilities, respectively. Of the $24 million as of December 31, 2014 , $(4) million and $(8) million were netted against current assets and noncurrent assets, respectively, and $32 million and $4 million were netted against current liabilities and noncurrent liabilities, respectively. Certain of Power’s derivative instruments contain provisions that require Power to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon Power’s credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty. These credit risk-related contingent features stipulate that if Power were to be downgraded to a below investment grade rating, it would be required to provide additional collateral. This incremental collateral requirement can offset collateral requirements related to other derivative instruments that are assets with the same counterparty, where the contractual right of offset exists under applicable master agreements. Power also enters into commodity transactions on the New York Mercantile Exchange (NYMEX) and Intercontinental Exchange (ICE). The NYMEX and ICE clearing houses act as counterparties to each trade. Transactions on the NYMEX and ICE must adhere to comprehensive collateral and margin requirements. The aggregate fair value of all derivative instruments with credit risk-related contingent features in a liability position that are not fully collateralized (excluding transactions on the NYMEX and ICE that are fully collateralized) was $78 million and $127 million as of September 30, 2015 and December 31, 2014 , respectively. As of September 30, 2015 and December 31, 2014 , Power had the contractual right of offset of $12 million and $18 million , respectively, related to derivative instruments that are assets with the same counterparty under agreements and net of margin posted. If Power had been downgraded to a below investment grade rating, it would have had additional collateral obligations of $66 million and $109 million as of September 30, 2015 and December 31, 2014 , respectively, related to its derivatives, net of the contractual right of offset under master agreements and the application of collateral. This potential additional collateral is included in the $796 million and $945 million as of September 30, 2015 and December 31, 2014 , respectively, discussed in Note 8. Commitments and Contingent Liabilities . The following shows the effect on the Condensed Consolidated Statements of Operations and on Accumulated Other Comprehensive Income (AOCI) of derivative instruments designated as cash flow hedges for the three months ended September 30, 2015 and 2014 . Derivatives in Cash Flow Hedging Relationships Amount of Pre-Tax Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) Location of Pre-Tax Gain (Loss) Reclassified from AOCI into Income Amount of Pre-Tax Gain (Loss) Reclassified from AOCI into Income (Effective Portion) Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Three Months Ended Three Months Ended Three Months Ended September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 Millions PSEG Energy-Related Contracts $ 1 $ 3 Operating Revenues $ — $ 1 Operating Revenues $ — $ — Total PSEG $ 1 $ 3 $ — $ 1 $ — $ — Power Energy-Related Contracts $ 1 $ 3 Operating Revenues $ — $ 1 Operating Revenues $ — $ — Total Power $ 1 $ 3 $ — $ 1 $ — $ — The following shows the effect on the Condensed Consolidated Statements of Operations and on Accumulated Other Comprehensive Income (AOCI) of derivative instruments designated as cash flow hedges for the nine months ended September 30, 2015 and 2014 . Derivatives in Cash Flow Hedging Relationships Amount of Pre-Tax Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) Location of Pre-Tax Gain (Loss) Reclassified from AOCI into Income Amount of Pre-Tax Gain (Loss) Reclassified from AOCI into Income (Effective Portion) Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Nine Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 Millions PSEG Energy-Related Contracts $ 2 $ (4 ) Operating Revenues $ 17 $ (11 ) Operating Revenues $ — $ — Total PSEG $ 2 $ (4 ) $ 17 $ (11 ) $ — $ — Power Energy-Related Contracts $ 2 $ (4 ) Operating Revenues $ 17 $ (11 ) Operating Revenues $ — $ — Total Power $ 2 $ (4 ) $ 17 $ (11 ) $ — $ — The following reconciles the Accumulated Other Comprehensive Income for derivative activity included in the Accumulated Other Comprehensive Loss of PSEG on a pre-tax and after-tax basis. Accumulated Other Comprehensive Income Pre-Tax After-Tax Millions Balance as of December 31, 2014 $ 17 $ 10 Gain Recognized in AOCI 1 1 Less: Gain Reclassified into Income (17 ) (10 ) Balance as of June 30, 2015 $ 1 $ 1 Gain Recognized in AOCI 1 — — Less: Gain Reclassified into Income — — Balance as of September 30, 2015 $ 2 $ 1 The following shows the effect on the Condensed Consolidated Statements of Operations of derivative instruments not designated as hedging instruments or as normal purchases and sales for the three months and nine months ended September 30, 2015 and 2014 . Derivatives Not Designated as Hedges Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives Pre-Tax Gain (Loss) Recognized in Income on Derivatives Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions PSEG and Power Energy-Related Contracts Operating Revenues $ 154 $ 93 $ 202 $ (759 ) Energy-Related Contracts Energy Costs (4 ) (12 ) (4 ) 65 Total PSEG and Power $ 150 $ 81 $ 198 $ (694 ) Power’s derivative contracts reflected in the preceding tables include contracts to hedge the purchase and sale of electricity and natural gas and the purchase of fuel. Not all of these contracts qualify for hedge accounting. Most of these contracts are marked to market. The tables above do not include contracts for which Power has elected the NPNS exemption, such as its BGS contracts and certain other energy supply contracts that it has with other utilities and companies with retail load. In addition, PSEG has interest rate swaps designated as fair value hedges. The effect of these hedges was to reduce interest expense by $5 million for each of the three months and $15 million for each of the nine months ended September 30, 2015 and 2014 , respectively. The following reflects the gross volume, on an absolute value basis, of derivatives as of September 30, 2015 and December 31, 2014 . Type Notional Total PSEG Power PSE&G Millions As of September 30, 2015 Natural Gas Dth 193 — 154 39 Electricity MWh 291 — 291 — Financial Transmission Rights (FTRs) MWh 21 — 21 — Interest Rate Swaps U.S. Dollars 850 850 — — As of December 31, 2014 Natural Gas Dth 274 — 216 58 Electricity MWh 310 — 310 — FTRs MWh 15 — 15 — Interest Rate Swaps U.S. Dollars 850 850 — — Credit Risk Credit risk relates to the risk of loss that we would incur as a result of non-performance by counterparties pursuant to the terms of their contractual obligations. We have established credit policies that we believe significantly minimize credit risk. These policies include an evaluation of potential counterparties’ financial condition (including credit rating), collateral requirements under certain circumstances and the use of standardized agreements, which allow for the netting of positive and negative exposures associated with a single counterparty. In the event of non-performance or non-payment by a major counterparty, there may be a material adverse impact on Power’s and PSEG’s financial condition, results of operations or net cash flows. As of September 30, 2015 , 98% of the credit for Power’s operations was with investment grade counterparties. Credit exposure is defined as any positive results of netting accounts receivable/accounts payable and the forward value of open positions (which includes all financial instruments including derivatives and non-derivatives and normal purchases/normal sales). The following table provides information on Power’s credit risk from others, net of cash collateral, as of September 30, 2015 . It further delineates that exposure by the credit rating of the counterparties and provides guidance on the concentration of credit risk to individual counterparties and an indication of the quality of Power’s credit risk by credit rating of the counterparties. Rating Current Exposure Securities Held as Collateral Net Exposure Number of Counterparties >10% Net Exposure of Counterparties >10% Millions Millions Investment Grade—External Rating $ 348 $ 118 $ 230 2 $ 127 (A) Non-Investment Grade—External Rating 1 — 1 — — Investment Grade—No External Rating 11 — 11 — — Non-Investment Grade—No External Rating 4 — 4 — — Total $ 364 $ 118 $ 246 2 $ 127 (A) Represents net exposure of $87 million with PSE&G. The remaining net exposure of $40 million is with a non- affiliated power purchaser which is an investment grade counterparty. As of September 30, 2015, collateral held from counterparties where Power had credit exposure included $43 million in cash collateral and $75 million in letters of credit. As of September 30, 2015 , Power had 133 active counterparties. PSE&G’s supplier master agreements are approved by the BPU and govern the terms of its electric supply procurement contracts. These agreements define a supplier’s performance assurance requirements and allow a supplier to meet its credit requirements with a certain amount of unsecured credit. The amount of unsecured credit is determined based on the supplier’s credit ratings from the major credit rating agencies and the supplier’s tangible net worth. The credit position is based on the initial market price, which is the forward price of energy on the day the procurement transaction is executed, compared to the forward price curve for energy on the valuation day. To the extent that the forward price curve for energy exceeds the initial market price, the supplier is required to post a parental guaranty or other security instrument such as a letter of credit or cash, as collateral to the extent the credit exposure is greater than the supplier’s unsecured credit limit. As of September 30, 2015 , primarily all of the posted collateral was in the form of parental guarantees. The unsecured credit used by the suppliers represents PSE&G’s net credit exposure. PSE&G's suppliers’ credit exposure is calculated each business day. As of September 30, 2015 , PSE&G had no net credit exposure with suppliers, including Power. PSE&G is permitted to recover its costs of procuring energy through the BPU-approved BGS tariffs. PSE&G’s counterparty credit risk is mitigated by its ability to recover realized energy costs through customer rates. |
PSE And G [Member] | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Financial Risk Management Activities | Financial Risk Management Activities The operations of PSEG, Power and PSE&G are exposed to market risks from changes in commodity prices, interest rates and equity prices that could affect their results of operations and financial condition. Exposure to these risks is managed through normal operating and financing activities and, when appropriate, through hedging transactions. Hedging transactions use derivative instruments to create a relationship in which changes to the value of the assets, liabilities or anticipated transactions exposed to market risks are expected to be offset by changes in the value of these derivative instruments. Derivative accounting guidance requires that a derivative instrument be recognized as either an asset or a liability at fair value, with changes in fair value of the derivative recognized in earnings each period. Other accounting treatments are available through special election and designation provided that the derivative instrument meets specific, restrictive criteria, both at the time of designation and on an ongoing basis. These alternative permissible treatments include normal purchase normal sale (NPNS), cash flow hedge and fair value hedge accounting. PSEG, Power and PSE&G have applied the NPNS scope exception to certain derivative contracts for the forward sale of generation, power procurement agreements and fuel agreements. Transactions receiving NPNS treatment are accounted for upon settlement. For a derivative instrument that qualifies and is designated as a cash flow hedge, the changes in the fair value of such a derivative that are highly effective are recorded in Accumulated Other Comprehensive Income (Loss) until earnings are affected by the variability of cash flows of the hedged transaction. For a derivative instrument that qualifies and is designated as a fair value hedge, the gains or losses on the derivative as well as the offsetting losses or gains on the hedged item attributable to the hedged risk are recognized in earnings each period. Power and PSE&G enter into additional contracts that are derivatives, but do not qualify for or are not designated as either cash flow hedges or fair value hedges. These transactions are economic hedges and changes in the fair value of these contracts are recorded in earnings each period. Commodity Prices Within PSEG and its affiliate companies, Power has the most exposure to commodity price risk. Power is exposed to commodity price risk primarily relating to changes in the market price of electricity, fossil fuels and other commodities. Fluctuations in market prices result from changes in supply and demand, fuel costs, market conditions, weather, state and federal regulatory policies, environmental policies, transmission availability and other factors. Power uses a variety of derivative and non-derivative instruments to manage the commodity price risk of its electric generation facilities, including physical and financial transactions in the wholesale energy markets to mitigate the effects of adverse movements in fuel and electricity prices. The fair value for the majority of these contracts is obtained from quoted market sources. Modeling techniques using assumptions reflective of current market rates, yield curves and forward prices are used to interpolate certain prices when no quoted market exists. Cash Flow Hedges PSEG and Power use forward sale contracts, swaps and futures contracts to hedge certain forecasted natural gas sales made to support the BGSS contract with PSE&G. These derivative transactions qualify and are designated as cash flow hedges. As of September 30, 2015 and December 31, 2014 , the fair value and the impact on Accumulated Other Comprehensive Income (Loss) associated with accounting hedge activity were as follows: As of As of September 30, December 31, Millions Fair Value of Cash Flow Hedges $ 2 $ 18 Impact on Accumulated Other Comprehensive Income (Loss) (after tax) $ 1 $ 10 The expiration date of the longest-dated cash flow hedge at Power is in December 2015 . Power’s remaining $1 million of after-tax unrealized gains on these derivatives is expected to be reclassified to earnings during the next 12 months. There was no ineffectiveness associated with qualifying hedges as of September 30, 2015 . Economic Hedges Power enters into derivative contracts that do not qualify or are not designated as either cash flow or fair value hedges. Power enters into financial options, futures, swaps, fuel purchases and forward purchases and sales of electricity. These transactions are economic hedges, intended to mitigate exposure to fluctuations in commodity prices and optimize the value of Power's expected generation. Changes in the fair market value of these contracts are recorded in earnings. PSE&G is a party to certain long-term natural gas sales derivative contracts to optimize its pipeline capacity utilization. Changes in the fair market value of these contracts are recorded in Regulatory Assets and Regulatory Liabilities. Interest Rates PSEG, Power and PSE&G are subject to the risk of fluctuating interest rates in the normal course of business. Exposure to this risk is managed by targeting a balanced debt maturity profile which limits refinancing in any given period or interest rate environment. In addition, they have used a mix of fixed and floating rate debt and interest rate swaps. Fair Value Hedges PSEG enters into fair value hedges to convert fixed-rate debt into variable-rate debt. As of September 30, 2015 , PSEG had interest rate swaps outstanding totaling $850 million . These swaps convert Power’s $300 million of 5.5% Senior Notes due December 2015, $300 million of Power’s $303 million of 5.32% Senior Notes due September 2016 and Power’s $250 million of 2.75% Senior Notes due September 2016 into variable-rate debt. These interest rate swaps are designated and effective as fair value hedges. The fair value changes of the interest rate swaps are fully offset by the changes in the fair value of the underlying forecasted interest payments of the debt. As of September 30, 2015 and December 31, 2014 , the fair value of all the underlying hedges was $11 million and $22 million , respectively. Cash Flow Hedges PSEG uses interest rate swaps and other derivatives, which are designated and effective as cash flow hedges, to manage its exposure to the variability of cash flows, primarily related to variable-rate debt instruments. The Accumulated Other Comprehensive Income (Loss) (after tax) related to interest rate derivatives designated as cash flow hedges was immaterial as of September 30, 2015 and December 31, 2014 , respectively. Fair Values of Derivative Instruments The following are the fair values of derivative instruments on the Condensed Consolidated Balance Sheets. The following tables also include disclosures for offsetting derivative assets and liabilities which are subject to a master netting or similar agreement. In general, the terms of the agreements provide that in the event of an early termination the counterparties have the right to offset amounts owed or owing under that and any other agreement with the same counterparty. Accordingly, and in accordance with our accounting policy, these positions have been offset on the Condensed Consolidated Balance Sheets of Power, PSE&G and PSEG. The following tabular disclosure does not include the offsetting of trade receivables and payables. As of September 30, 2015 Power (A) PSE&G (A) PSEG (A) Consolidated Cash Flow Hedges Not Designated Not Designated Fair Value Hedges Balance Sheet Location Energy- Related Contracts Energy- Related Contracts Netting (B) Total Power Energy- Related Contracts Interest Rate Swaps Total Derivatives Millions Derivative Contracts Current Assets $ 2 $ 413 $ (268 ) $ 147 $ 4 $ 11 $ 162 Noncurrent Assets — 284 (193 ) 91 — — 91 Total Mark-to-Market Derivative Assets $ 2 $ 697 $ (461 ) $ 238 $ 4 $ 11 $ 253 Derivative Contracts Current Liabilities $ — $ (311 ) $ 241 $ (70 ) $ — $ — $ (70 ) Noncurrent Liabilities — (178 ) 162 (16 ) (7 ) — (23 ) Total Mark-to-Market Derivative (Liabilities) $ — $ (489 ) $ 403 $ (86 ) $ (7 ) $ — $ (93 ) Total Net Mark-to-Market Derivative Assets (Liabilities) $ 2 $ 208 $ (58 ) $ 152 $ (3 ) $ 11 $ 160 As of December 31, 2014 Power (A) PSE&G (A) PSEG (A) Consolidated Cash Flow Hedges Not Designated Not Designated Fair Value Hedges Balance Sheet Location Energy- Related Contracts Energy- Related Contracts Netting (B) Total Power Energy- Related Contracts Interest Rate Swaps Total Derivatives Millions Derivative Contracts Current Assets $ 18 $ 597 $ (408 ) $ 207 $ 18 $ 15 $ 240 Noncurrent Assets — 171 (109 ) 62 8 7 77 Total Mark-to-Market Derivative Assets $ 18 $ 768 $ (517 ) $ 269 $ 26 $ 22 $ 317 Derivative Contracts Current Liabilities $ — $ (568 ) $ 436 $ (132 ) $ — $ — $ (132 ) Noncurrent Liabilities — (138 ) 105 (33 ) — — (33 ) Total Mark-to-Market Derivative (Liabilities) $ — $ (706 ) $ 541 $ (165 ) $ — $ — $ (165 ) Total Net Mark-to-Market Derivative Assets (Liabilities) $ 18 $ 62 $ 24 $ 104 $ 26 $ 22 $ 152 (A) Substantially all of Power's and PSEG's derivative instruments are contracts subject to master netting agreements. Contracts not subject to master netting or similar agreements are immaterial and did not have any collateral posted or received as of September 30, 2015 and December 31, 2014 . PSE&G does not have any derivative contracts subject to master netting or similar agreements. (B) Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral received or posted that has been allocated to derivative positions, where the right of offset exists, has been offset on the Condensed Consolidated Balance Sheets. As of September 30, 2015 and December 31, 2014 , net cash collateral (received) paid of $(58) million and $24 million , respectively, were netted against the corresponding net derivative contract positions. Of the $(58) million as of September 30, 2015 , $(32) million and $(38) million of cash collateral were netted against current assets and noncurrent assets, respectively, and $5 million and $7 million were netted against current liabilities and noncurrent liabilities, respectively. Of the $24 million as of December 31, 2014 , $(4) million and $(8) million were netted against current assets and noncurrent assets, respectively, and $32 million and $4 million were netted against current liabilities and noncurrent liabilities, respectively. Certain of Power’s derivative instruments contain provisions that require Power to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon Power’s credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty. These credit risk-related contingent features stipulate that if Power were to be downgraded to a below investment grade rating, it would be required to provide additional collateral. This incremental collateral requirement can offset collateral requirements related to other derivative instruments that are assets with the same counterparty, where the contractual right of offset exists under applicable master agreements. Power also enters into commodity transactions on the New York Mercantile Exchange (NYMEX) and Intercontinental Exchange (ICE). The NYMEX and ICE clearing houses act as counterparties to each trade. Transactions on the NYMEX and ICE must adhere to comprehensive collateral and margin requirements. The aggregate fair value of all derivative instruments with credit risk-related contingent features in a liability position that are not fully collateralized (excluding transactions on the NYMEX and ICE that are fully collateralized) was $78 million and $127 million as of September 30, 2015 and December 31, 2014 , respectively. As of September 30, 2015 and December 31, 2014 , Power had the contractual right of offset of $12 million and $18 million , respectively, related to derivative instruments that are assets with the same counterparty under agreements and net of margin posted. If Power had been downgraded to a below investment grade rating, it would have had additional collateral obligations of $66 million and $109 million as of September 30, 2015 and December 31, 2014 , respectively, related to its derivatives, net of the contractual right of offset under master agreements and the application of collateral. This potential additional collateral is included in the $796 million and $945 million as of September 30, 2015 and December 31, 2014 , respectively, discussed in Note 8. Commitments and Contingent Liabilities . The following shows the effect on the Condensed Consolidated Statements of Operations and on Accumulated Other Comprehensive Income (AOCI) of derivative instruments designated as cash flow hedges for the three months ended September 30, 2015 and 2014 . Derivatives in Cash Flow Hedging Relationships Amount of Pre-Tax Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) Location of Pre-Tax Gain (Loss) Reclassified from AOCI into Income Amount of Pre-Tax Gain (Loss) Reclassified from AOCI into Income (Effective Portion) Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Three Months Ended Three Months Ended Three Months Ended September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 Millions PSEG Energy-Related Contracts $ 1 $ 3 Operating Revenues $ — $ 1 Operating Revenues $ — $ — Total PSEG $ 1 $ 3 $ — $ 1 $ — $ — Power Energy-Related Contracts $ 1 $ 3 Operating Revenues $ — $ 1 Operating Revenues $ — $ — Total Power $ 1 $ 3 $ — $ 1 $ — $ — The following shows the effect on the Condensed Consolidated Statements of Operations and on Accumulated Other Comprehensive Income (AOCI) of derivative instruments designated as cash flow hedges for the nine months ended September 30, 2015 and 2014 . Derivatives in Cash Flow Hedging Relationships Amount of Pre-Tax Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) Location of Pre-Tax Gain (Loss) Reclassified from AOCI into Income Amount of Pre-Tax Gain (Loss) Reclassified from AOCI into Income (Effective Portion) Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Nine Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 Millions PSEG Energy-Related Contracts $ 2 $ (4 ) Operating Revenues $ 17 $ (11 ) Operating Revenues $ — $ — Total PSEG $ 2 $ (4 ) $ 17 $ (11 ) $ — $ — Power Energy-Related Contracts $ 2 $ (4 ) Operating Revenues $ 17 $ (11 ) Operating Revenues $ — $ — Total Power $ 2 $ (4 ) $ 17 $ (11 ) $ — $ — The following reconciles the Accumulated Other Comprehensive Income for derivative activity included in the Accumulated Other Comprehensive Loss of PSEG on a pre-tax and after-tax basis. Accumulated Other Comprehensive Income Pre-Tax After-Tax Millions Balance as of December 31, 2014 $ 17 $ 10 Gain Recognized in AOCI 1 1 Less: Gain Reclassified into Income (17 ) (10 ) Balance as of June 30, 2015 $ 1 $ 1 Gain Recognized in AOCI 1 — — Less: Gain Reclassified into Income — — Balance as of September 30, 2015 $ 2 $ 1 The following shows the effect on the Condensed Consolidated Statements of Operations of derivative instruments not designated as hedging instruments or as normal purchases and sales for the three months and nine months ended September 30, 2015 and 2014 . Derivatives Not Designated as Hedges Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives Pre-Tax Gain (Loss) Recognized in Income on Derivatives Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions PSEG and Power Energy-Related Contracts Operating Revenues $ 154 $ 93 $ 202 $ (759 ) Energy-Related Contracts Energy Costs (4 ) (12 ) (4 ) 65 Total PSEG and Power $ 150 $ 81 $ 198 $ (694 ) Power’s derivative contracts reflected in the preceding tables include contracts to hedge the purchase and sale of electricity and natural gas and the purchase of fuel. Not all of these contracts qualify for hedge accounting. Most of these contracts are marked to market. The tables above do not include contracts for which Power has elected the NPNS exemption, such as its BGS contracts and certain other energy supply contracts that it has with other utilities and companies with retail load. In addition, PSEG has interest rate swaps designated as fair value hedges. The effect of these hedges was to reduce interest expense by $5 million for each of the three months and $15 million for each of the nine months ended September 30, 2015 and 2014 , respectively. The following reflects the gross volume, on an absolute value basis, of derivatives as of September 30, 2015 and December 31, 2014 . Type Notional Total PSEG Power PSE&G Millions As of September 30, 2015 Natural Gas Dth 193 — 154 39 Electricity MWh 291 — 291 — Financial Transmission Rights (FTRs) MWh 21 — 21 — Interest Rate Swaps U.S. Dollars 850 850 — — As of December 31, 2014 Natural Gas Dth 274 — 216 58 Electricity MWh 310 — 310 — FTRs MWh 15 — 15 — Interest Rate Swaps U.S. Dollars 850 850 — — Credit Risk Credit risk relates to the risk of loss that we would incur as a result of non-performance by counterparties pursuant to the terms of their contractual obligations. We have established credit policies that we believe significantly minimize credit risk. These policies include an evaluation of potential counterparties’ financial condition (including credit rating), collateral requirements under certain circumstances and the use of standardized agreements, which allow for the netting of positive and negative exposures associated with a single counterparty. In the event of non-performance or non-payment by a major counterparty, there may be a material adverse impact on Power’s and PSEG’s financial condition, results of operations or net cash flows. As of September 30, 2015 , 98% of the credit for Power’s operations was with investment grade counterparties. Credit exposure is defined as any positive results of netting accounts receivable/accounts payable and the forward value of open positions (which includes all financial instruments including derivatives and non-derivatives and normal purchases/normal sales). The following table provides information on Power’s credit risk from others, net of cash collateral, as of September 30, 2015 . It further delineates that exposure by the credit rating of the counterparties and provides guidance on the concentration of credit risk to individual counterparties and an indication of the quality of Power’s credit risk by credit rating of the counterparties. Rating Current Exposure Securities Held as Collateral Net Exposure Number of Counterparties >10% Net Exposure of Counterparties >10% Millions Millions Investment Grade—External Rating $ 348 $ 118 $ 230 2 $ 127 (A) Non-Investment Grade—External Rating 1 — 1 — — Investment Grade—No External Rating 11 — 11 — — Non-Investment Grade—No External Rating 4 — 4 — — Total $ 364 $ 118 $ 246 2 $ 127 (A) Represents net exposure of $87 million with PSE&G. The remaining net exposure of $40 million is with a non- affiliated power purchaser which is an investment grade counterparty. As of September 30, 2015, collateral held from counterparties where Power had credit exposure included $43 million in cash collateral and $75 million in letters of credit. As of September 30, 2015 , Power had 133 active counterparties. PSE&G’s supplier master agreements are approved by the BPU and govern the terms of its electric supply procurement contracts. These agreements define a supplier’s performance assurance requirements and allow a supplier to meet its credit requirements with a certain amount of unsecured credit. The amount of unsecured credit is determined based on the supplier’s credit ratings from the major credit rating agencies and the supplier’s tangible net worth. The credit position is based on the initial market price, which is the forward price of energy on the day the procurement transaction is executed, compared to the forward price curve for energy on the valuation day. To the extent that the forward price curve for energy exceeds the initial market price, the supplier is required to post a parental guaranty or other security instrument such as a letter of credit or cash, as collateral to the extent the credit exposure is greater than the supplier’s unsecured credit limit. As of September 30, 2015 , primarily all of the posted collateral was in the form of parental guarantees. The unsecured credit used by the suppliers represents PSE&G’s net credit exposure. PSE&G's suppliers’ credit exposure is calculated each business day. As of September 30, 2015 , PSE&G had no net credit exposure with suppliers, including Power. PSE&G is permitted to recover its costs of procuring energy through the BPU-approved BGS tariffs. PSE&G’s counterparty credit risk is mitigated by its ability to recover realized energy costs through customer rates. |
Power [Member] | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Financial Risk Management Activities | Financial Risk Management Activities The operations of PSEG, Power and PSE&G are exposed to market risks from changes in commodity prices, interest rates and equity prices that could affect their results of operations and financial condition. Exposure to these risks is managed through normal operating and financing activities and, when appropriate, through hedging transactions. Hedging transactions use derivative instruments to create a relationship in which changes to the value of the assets, liabilities or anticipated transactions exposed to market risks are expected to be offset by changes in the value of these derivative instruments. Derivative accounting guidance requires that a derivative instrument be recognized as either an asset or a liability at fair value, with changes in fair value of the derivative recognized in earnings each period. Other accounting treatments are available through special election and designation provided that the derivative instrument meets specific, restrictive criteria, both at the time of designation and on an ongoing basis. These alternative permissible treatments include normal purchase normal sale (NPNS), cash flow hedge and fair value hedge accounting. PSEG, Power and PSE&G have applied the NPNS scope exception to certain derivative contracts for the forward sale of generation, power procurement agreements and fuel agreements. Transactions receiving NPNS treatment are accounted for upon settlement. For a derivative instrument that qualifies and is designated as a cash flow hedge, the changes in the fair value of such a derivative that are highly effective are recorded in Accumulated Other Comprehensive Income (Loss) until earnings are affected by the variability of cash flows of the hedged transaction. For a derivative instrument that qualifies and is designated as a fair value hedge, the gains or losses on the derivative as well as the offsetting losses or gains on the hedged item attributable to the hedged risk are recognized in earnings each period. Power and PSE&G enter into additional contracts that are derivatives, but do not qualify for or are not designated as either cash flow hedges or fair value hedges. These transactions are economic hedges and changes in the fair value of these contracts are recorded in earnings each period. Commodity Prices Within PSEG and its affiliate companies, Power has the most exposure to commodity price risk. Power is exposed to commodity price risk primarily relating to changes in the market price of electricity, fossil fuels and other commodities. Fluctuations in market prices result from changes in supply and demand, fuel costs, market conditions, weather, state and federal regulatory policies, environmental policies, transmission availability and other factors. Power uses a variety of derivative and non-derivative instruments to manage the commodity price risk of its electric generation facilities, including physical and financial transactions in the wholesale energy markets to mitigate the effects of adverse movements in fuel and electricity prices. The fair value for the majority of these contracts is obtained from quoted market sources. Modeling techniques using assumptions reflective of current market rates, yield curves and forward prices are used to interpolate certain prices when no quoted market exists. Cash Flow Hedges PSEG and Power use forward sale contracts, swaps and futures contracts to hedge certain forecasted natural gas sales made to support the BGSS contract with PSE&G. These derivative transactions qualify and are designated as cash flow hedges. As of September 30, 2015 and December 31, 2014 , the fair value and the impact on Accumulated Other Comprehensive Income (Loss) associated with accounting hedge activity were as follows: As of As of September 30, December 31, Millions Fair Value of Cash Flow Hedges $ 2 $ 18 Impact on Accumulated Other Comprehensive Income (Loss) (after tax) $ 1 $ 10 The expiration date of the longest-dated cash flow hedge at Power is in December 2015 . Power’s remaining $1 million of after-tax unrealized gains on these derivatives is expected to be reclassified to earnings during the next 12 months. There was no ineffectiveness associated with qualifying hedges as of September 30, 2015 . Economic Hedges Power enters into derivative contracts that do not qualify or are not designated as either cash flow or fair value hedges. Power enters into financial options, futures, swaps, fuel purchases and forward purchases and sales of electricity. These transactions are economic hedges, intended to mitigate exposure to fluctuations in commodity prices and optimize the value of Power's expected generation. Changes in the fair market value of these contracts are recorded in earnings. PSE&G is a party to certain long-term natural gas sales derivative contracts to optimize its pipeline capacity utilization. Changes in the fair market value of these contracts are recorded in Regulatory Assets and Regulatory Liabilities. Interest Rates PSEG, Power and PSE&G are subject to the risk of fluctuating interest rates in the normal course of business. Exposure to this risk is managed by targeting a balanced debt maturity profile which limits refinancing in any given period or interest rate environment. In addition, they have used a mix of fixed and floating rate debt and interest rate swaps. Fair Value Hedges PSEG enters into fair value hedges to convert fixed-rate debt into variable-rate debt. As of September 30, 2015 , PSEG had interest rate swaps outstanding totaling $850 million . These swaps convert Power’s $300 million of 5.5% Senior Notes due December 2015, $300 million of Power’s $303 million of 5.32% Senior Notes due September 2016 and Power’s $250 million of 2.75% Senior Notes due September 2016 into variable-rate debt. These interest rate swaps are designated and effective as fair value hedges. The fair value changes of the interest rate swaps are fully offset by the changes in the fair value of the underlying forecasted interest payments of the debt. As of September 30, 2015 and December 31, 2014 , the fair value of all the underlying hedges was $11 million and $22 million , respectively. Cash Flow Hedges PSEG uses interest rate swaps and other derivatives, which are designated and effective as cash flow hedges, to manage its exposure to the variability of cash flows, primarily related to variable-rate debt instruments. The Accumulated Other Comprehensive Income (Loss) (after tax) related to interest rate derivatives designated as cash flow hedges was immaterial as of September 30, 2015 and December 31, 2014 , respectively. Fair Values of Derivative Instruments The following are the fair values of derivative instruments on the Condensed Consolidated Balance Sheets. The following tables also include disclosures for offsetting derivative assets and liabilities which are subject to a master netting or similar agreement. In general, the terms of the agreements provide that in the event of an early termination the counterparties have the right to offset amounts owed or owing under that and any other agreement with the same counterparty. Accordingly, and in accordance with our accounting policy, these positions have been offset on the Condensed Consolidated Balance Sheets of Power, PSE&G and PSEG. The following tabular disclosure does not include the offsetting of trade receivables and payables. As of September 30, 2015 Power (A) PSE&G (A) PSEG (A) Consolidated Cash Flow Hedges Not Designated Not Designated Fair Value Hedges Balance Sheet Location Energy- Related Contracts Energy- Related Contracts Netting (B) Total Power Energy- Related Contracts Interest Rate Swaps Total Derivatives Millions Derivative Contracts Current Assets $ 2 $ 413 $ (268 ) $ 147 $ 4 $ 11 $ 162 Noncurrent Assets — 284 (193 ) 91 — — 91 Total Mark-to-Market Derivative Assets $ 2 $ 697 $ (461 ) $ 238 $ 4 $ 11 $ 253 Derivative Contracts Current Liabilities $ — $ (311 ) $ 241 $ (70 ) $ — $ — $ (70 ) Noncurrent Liabilities — (178 ) 162 (16 ) (7 ) — (23 ) Total Mark-to-Market Derivative (Liabilities) $ — $ (489 ) $ 403 $ (86 ) $ (7 ) $ — $ (93 ) Total Net Mark-to-Market Derivative Assets (Liabilities) $ 2 $ 208 $ (58 ) $ 152 $ (3 ) $ 11 $ 160 As of December 31, 2014 Power (A) PSE&G (A) PSEG (A) Consolidated Cash Flow Hedges Not Designated Not Designated Fair Value Hedges Balance Sheet Location Energy- Related Contracts Energy- Related Contracts Netting (B) Total Power Energy- Related Contracts Interest Rate Swaps Total Derivatives Millions Derivative Contracts Current Assets $ 18 $ 597 $ (408 ) $ 207 $ 18 $ 15 $ 240 Noncurrent Assets — 171 (109 ) 62 8 7 77 Total Mark-to-Market Derivative Assets $ 18 $ 768 $ (517 ) $ 269 $ 26 $ 22 $ 317 Derivative Contracts Current Liabilities $ — $ (568 ) $ 436 $ (132 ) $ — $ — $ (132 ) Noncurrent Liabilities — (138 ) 105 (33 ) — — (33 ) Total Mark-to-Market Derivative (Liabilities) $ — $ (706 ) $ 541 $ (165 ) $ — $ — $ (165 ) Total Net Mark-to-Market Derivative Assets (Liabilities) $ 18 $ 62 $ 24 $ 104 $ 26 $ 22 $ 152 (A) Substantially all of Power's and PSEG's derivative instruments are contracts subject to master netting agreements. Contracts not subject to master netting or similar agreements are immaterial and did not have any collateral posted or received as of September 30, 2015 and December 31, 2014 . PSE&G does not have any derivative contracts subject to master netting or similar agreements. (B) Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral received or posted that has been allocated to derivative positions, where the right of offset exists, has been offset on the Condensed Consolidated Balance Sheets. As of September 30, 2015 and December 31, 2014 , net cash collateral (received) paid of $(58) million and $24 million , respectively, were netted against the corresponding net derivative contract positions. Of the $(58) million as of September 30, 2015 , $(32) million and $(38) million of cash collateral were netted against current assets and noncurrent assets, respectively, and $5 million and $7 million were netted against current liabilities and noncurrent liabilities, respectively. Of the $24 million as of December 31, 2014 , $(4) million and $(8) million were netted against current assets and noncurrent assets, respectively, and $32 million and $4 million were netted against current liabilities and noncurrent liabilities, respectively. Certain of Power’s derivative instruments contain provisions that require Power to post collateral. This collateral may be posted in the form of cash or credit support with thresholds contingent upon Power’s credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty. These credit risk-related contingent features stipulate that if Power were to be downgraded to a below investment grade rating, it would be required to provide additional collateral. This incremental collateral requirement can offset collateral requirements related to other derivative instruments that are assets with the same counterparty, where the contractual right of offset exists under applicable master agreements. Power also enters into commodity transactions on the New York Mercantile Exchange (NYMEX) and Intercontinental Exchange (ICE). The NYMEX and ICE clearing houses act as counterparties to each trade. Transactions on the NYMEX and ICE must adhere to comprehensive collateral and margin requirements. The aggregate fair value of all derivative instruments with credit risk-related contingent features in a liability position that are not fully collateralized (excluding transactions on the NYMEX and ICE that are fully collateralized) was $78 million and $127 million as of September 30, 2015 and December 31, 2014 , respectively. As of September 30, 2015 and December 31, 2014 , Power had the contractual right of offset of $12 million and $18 million , respectively, related to derivative instruments that are assets with the same counterparty under agreements and net of margin posted. If Power had been downgraded to a below investment grade rating, it would have had additional collateral obligations of $66 million and $109 million as of September 30, 2015 and December 31, 2014 , respectively, related to its derivatives, net of the contractual right of offset under master agreements and the application of collateral. This potential additional collateral is included in the $796 million and $945 million as of September 30, 2015 and December 31, 2014 , respectively, discussed in Note 8. Commitments and Contingent Liabilities . The following shows the effect on the Condensed Consolidated Statements of Operations and on Accumulated Other Comprehensive Income (AOCI) of derivative instruments designated as cash flow hedges for the three months ended September 30, 2015 and 2014 . Derivatives in Cash Flow Hedging Relationships Amount of Pre-Tax Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) Location of Pre-Tax Gain (Loss) Reclassified from AOCI into Income Amount of Pre-Tax Gain (Loss) Reclassified from AOCI into Income (Effective Portion) Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Three Months Ended Three Months Ended Three Months Ended September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 Millions PSEG Energy-Related Contracts $ 1 $ 3 Operating Revenues $ — $ 1 Operating Revenues $ — $ — Total PSEG $ 1 $ 3 $ — $ 1 $ — $ — Power Energy-Related Contracts $ 1 $ 3 Operating Revenues $ — $ 1 Operating Revenues $ — $ — Total Power $ 1 $ 3 $ — $ 1 $ — $ — The following shows the effect on the Condensed Consolidated Statements of Operations and on Accumulated Other Comprehensive Income (AOCI) of derivative instruments designated as cash flow hedges for the nine months ended September 30, 2015 and 2014 . Derivatives in Cash Flow Hedging Relationships Amount of Pre-Tax Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) Location of Pre-Tax Gain (Loss) Reclassified from AOCI into Income Amount of Pre-Tax Gain (Loss) Reclassified from AOCI into Income (Effective Portion) Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Nine Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 Millions PSEG Energy-Related Contracts $ 2 $ (4 ) Operating Revenues $ 17 $ (11 ) Operating Revenues $ — $ — Total PSEG $ 2 $ (4 ) $ 17 $ (11 ) $ — $ — Power Energy-Related Contracts $ 2 $ (4 ) Operating Revenues $ 17 $ (11 ) Operating Revenues $ — $ — Total Power $ 2 $ (4 ) $ 17 $ (11 ) $ — $ — The following reconciles the Accumulated Other Comprehensive Income for derivative activity included in the Accumulated Other Comprehensive Loss of PSEG on a pre-tax and after-tax basis. Accumulated Other Comprehensive Income Pre-Tax After-Tax Millions Balance as of December 31, 2014 $ 17 $ 10 Gain Recognized in AOCI 1 1 Less: Gain Reclassified into Income (17 ) (10 ) Balance as of June 30, 2015 $ 1 $ 1 Gain Recognized in AOCI 1 — — Less: Gain Reclassified into Income — — Balance as of September 30, 2015 $ 2 $ 1 The following shows the effect on the Condensed Consolidated Statements of Operations of derivative instruments not designated as hedging instruments or as normal purchases and sales for the three months and nine months ended September 30, 2015 and 2014 . Derivatives Not Designated as Hedges Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives Pre-Tax Gain (Loss) Recognized in Income on Derivatives Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions PSEG and Power Energy-Related Contracts Operating Revenues $ 154 $ 93 $ 202 $ (759 ) Energy-Related Contracts Energy Costs (4 ) (12 ) (4 ) 65 Total PSEG and Power $ 150 $ 81 $ 198 $ (694 ) Power’s derivative contracts reflected in the preceding tables include contracts to hedge the purchase and sale of electricity and natural gas and the purchase of fuel. Not all of these contracts qualify for hedge accounting. Most of these contracts are marked to market. The tables above do not include contracts for which Power has elected the NPNS exemption, such as its BGS contracts and certain other energy supply contracts that it has with other utilities and companies with retail load. In addition, PSEG has interest rate swaps designated as fair value hedges. The effect of these hedges was to reduce interest expense by $5 million for each of the three months and $15 million for each of the nine months ended September 30, 2015 and 2014 , respectively. The following reflects the gross volume, on an absolute value basis, of derivatives as of September 30, 2015 and December 31, 2014 . Type Notional Total PSEG Power PSE&G Millions As of September 30, 2015 Natural Gas Dth 193 — 154 39 Electricity MWh 291 — 291 — Financial Transmission Rights (FTRs) MWh 21 — 21 — Interest Rate Swaps U.S. Dollars 850 850 — — As of December 31, 2014 Natural Gas Dth 274 — 216 58 Electricity MWh 310 — 310 — FTRs MWh 15 — 15 — Interest Rate Swaps U.S. Dollars 850 850 — — Credit Risk Credit risk relates to the risk of loss that we would incur as a result of non-performance by counterparties pursuant to the terms of their contractual obligations. We have established credit policies that we believe significantly minimize credit risk. These policies include an evaluation of potential counterparties’ financial condition (including credit rating), collateral requirements under certain circumstances and the use of standardized agreements, which allow for the netting of positive and negative exposures associated with a single counterparty. In the event of non-performance or non-payment by a major counterparty, there may be a material adverse impact on Power’s and PSEG’s financial condition, results of operations or net cash flows. As of September 30, 2015 , 98% of the credit for Power’s operations was with investment grade counterparties. Credit exposure is defined as any positive results of netting accounts receivable/accounts payable and the forward value of open positions (which includes all financial instruments including derivatives and non-derivatives and normal purchases/normal sales). The following table provides information on Power’s credit risk from others, net of cash collateral, as of September 30, 2015 . It further delineates that exposure by the credit rating of the counterparties and provides guidance on the concentration of credit risk to individual counterparties and an indication of the quality of Power’s credit risk by credit rating of the counterparties. Rating Current Exposure Securities Held as Collateral Net Exposure Number of Counterparties >10% Net Exposure of Counterparties >10% Millions Millions Investment Grade—External Rating $ 348 $ 118 $ 230 2 $ 127 (A) Non-Investment Grade—External Rating 1 — 1 — — Investment Grade—No External Rating 11 — 11 — — Non-Investment Grade—No External Rating 4 — 4 — — Total $ 364 $ 118 $ 246 2 $ 127 (A) Represents net exposure of $87 million with PSE&G. The remaining net exposure of $40 million is with a non- affiliated power purchaser which is an investment grade counterparty. As of September 30, 2015, collateral held from counterparties where Power had credit exposure included $43 million in cash collateral and $75 million in letters of credit. As of September 30, 2015 , Power had 133 active counterparties. PSE&G’s supplier master agreements are approved by the BPU and govern the terms of its electric supply procurement contracts. These agreements define a supplier’s performance assurance requirements and allow a supplier to meet its credit requirements with a certain amount of unsecured credit. The amount of unsecured credit is determined based on the supplier’s credit ratings from the major credit rating agencies and the supplier’s tangible net worth. The credit position is based on the initial market price, which is the forward price of energy on the day the procurement transaction is executed, compared to the forward price curve for energy on the valuation day. To the extent that the forward price curve for energy exceeds the initial market price, the supplier is required to post a parental guaranty or other security instrument such as a letter of credit or cash, as collateral to the extent the credit exposure is greater than the supplier’s unsecured credit limit. As of September 30, 2015 , primarily all of the posted collateral was in the form of parental guarantees. The unsecured credit used by the suppliers represents PSE&G’s net credit exposure. PSE&G's suppliers’ credit exposure is calculated each business day. As of September 30, 2015 , PSE&G had no net credit exposure with suppliers, including Power. PSE&G is permitted to recover its costs of procuring energy through the BPU-approved BGS tariffs. PSE&G’s counterparty credit risk is mitigated by its ability to recover realized energy costs through customer rates. |
Fair Value Measurements
Fair Value Measurements | 9 Months Ended |
Sep. 30, 2015 | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value Measurements | Fair Value Measurements Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Accounting guidance for fair value measurement emphasizes that fair value is a market-based measurement, not an entity-specific measurement, and establishes a fair value hierarchy that distinguishes between assumptions based on market data obtained from independent sources and those based on an entity’s own assumptions. The hierarchy prioritizes the inputs to fair value measurement into three levels: Level 1—measurements utilize quoted prices (unadjusted) in active markets for identical assets or liabilities that PSEG, PSE&G and Power have the ability to access. These consist primarily of listed equity securities and money market mutual funds. Level 2—measurements include quoted prices for similar assets and liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, and other observable inputs such as interest rates and yield curves that are observable at commonly quoted intervals. These consist primarily of non-exchange traded derivatives such as forward contracts or options and most fixed income securities. Level 3—measurements use unobservable inputs for assets or liabilities, based on the best information available and might include an entity’s own data and assumptions. In some valuations, the inputs used may fall into different levels of the hierarchy. In these cases, the financial instrument’s level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. As of September 30, 2015 , these consisted primarily of long-term gas supply contracts and certain electric load contracts. The following tables present information about PSEG’s, PSE&G’s and Power's respective assets and (liabilities) measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014 , including the fair value measurements and the levels of inputs used in determining those fair values. Amounts shown for PSEG include the amounts shown for PSE&G and Power. Recurring Fair Value Measurements as of September 30, 2015 Description Total Netting (E) Quoted Market Prices for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Millions PSEG Assets: Cash Equivalents (A) $ 226 $ — $ 226 $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 242 $ (461 ) $ — $ 694 $ 9 Interest Rate Swaps (C) $ 11 $ — $ — $ 11 $ — NDT Fund (D) Equity Securities $ 825 $ — $ 824 $ 1 $ — Debt Securities—Govt Obligations $ 454 $ — $ — $ 454 $ — Debt Securities—Other $ 401 $ — $ — $ 401 $ — Other Securities $ 35 $ — $ 35 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 20 $ — $ 20 $ — $ — Debt Securities—Govt Obligations $ 106 $ — $ — $ 106 $ — Debt Securities—Other $ 84 $ — $ — $ 84 $ — Other Securities $ 1 $ — $ 1 $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (93 ) $ 403 $ — $ (489 ) $ (7 ) PSE&G Assets: Cash Equivalents (A) $ — $ — $ — $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 4 $ — $ — $ — $ 4 Rabbi Trust (D) Equity Securities—Mutual Funds $ 4 $ — $ 4 $ — $ — Debt Securities—Govt Obligations $ 21 $ — $ — $ 21 $ — Debt Securities—Other $ 17 $ — $ — $ 17 $ — Other Securities $ — $ — $ — $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (7 ) $ — $ — $ — $ (7 ) Power Assets: Derivative Contracts: Energy-Related Contracts (B) $ 238 $ (461 ) $ — $ 694 $ 5 NDT Fund (D) Equity Securities $ 825 $ — $ 824 $ 1 $ — Debt Securities—Govt Obligations $ 454 $ — $ — $ 454 $ — Debt Securities—Other $ 401 $ — $ — $ 401 $ — Other Securities $ 35 $ — $ 35 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 26 $ — $ — $ 26 $ — Debt Securities—Other $ 21 $ — $ — $ 21 $ — Other Securities $ — $ — $ — $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (86 ) $ 403 $ — $ (489 ) $ — Recurring Fair Value Measurements as of December 31, 2014 Description Total Netting (E) Quoted Market Prices for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Millions PSEG Assets: Cash Equivalents (A) $ 365 $ — $ 365 $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 295 $ (517 ) $ — $ 774 $ 38 Interest Rate Swaps (C) $ 22 $ — $ — $ 22 $ — NDT Fund (D) Equity Securities $ 897 $ — $ 896 $ 1 $ — Debt Securities—Govt Obligations $ 438 $ — $ — $ 438 $ — Debt Securities—Other $ 339 $ — $ — $ 339 $ — Other Securities $ 106 $ — $ 106 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 23 $ — $ 23 $ — $ — Debt Securities—Govt Obligations $ 91 $ — $ — $ 91 $ — Debt Securities—Other $ 75 $ — $ — $ 75 $ — Other Securities $ 2 $ — $ — $ 2 $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (165 ) $ 541 $ — $ (705 ) $ (1 ) PSE&G Assets: Cash Equivalents (A) $ 294 $ — $ 294 $ — $ — Derivative Contracts: Energy Related Contracts (B) $ 26 $ — $ — $ — $ 26 Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 20 $ — $ — $ 20 $ — Debt Securities—Other $ 16 $ — $ — $ 16 $ — Other Securities $ — $ — $ — $ — $ — Power Assets: Derivative Contracts: Energy-Related Contracts (B) $ 269 $ (517 ) $ — $ 774 $ 12 NDT Fund (D) Equity Securities $ 897 $ — $ 896 $ 1 $ — Debt Securities—Govt Obligations $ 438 $ — $ — $ 438 $ — Debt Securities—Other $ 339 $ — $ — $ 339 $ — Other Securities $ 106 $ — $ 106 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 21 $ — $ — $ 21 $ — Debt Securities—Other $ 18 $ — $ — $ 18 $ — Other Securities $ 1 $ — $ — $ 1 $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (165 ) $ 541 $ — $ (705 ) $ (1 ) (A) Represents money market mutual funds. (B) Level 2—Fair values for energy-related contracts are obtained primarily using a market-based approach. Most derivative contracts (forward purchase or sale contracts and swaps) are valued using the average of the bid/ask midpoints from multiple broker or dealer quotes or auction prices. Prices used in the valuation process are also corroborated independently by management to determine that values are based on actual transaction data or, in the absence of transactions, bid and offers for the day. Examples may include certain exchange and non-exchange traded capacity and electricity contracts and natural gas physical or swap contracts based on market prices, basis adjustments and other premiums where adjustments and premiums are not considered significant to the overall inputs. Level 3—For energy-related contracts, which include more complex agreements where limited observable inputs or pricing information are available, modeling techniques are employed using assumptions reflective of contractual terms, current market rates, forward price curves, discount rates and risk factors, as applicable. Fair values of other energy contracts may be based on broker quotes that we cannot corroborate with actual market transaction data. (C) Interest rate swaps are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment. (D) The NDT Fund maintains investments in various equity and fixed income securities classified as “available for sale.” The Rabbi Trust maintains investments in an S&P 500 index fund and various fixed income securities classified as “available for sale.” These securities are generally valued with prices that are either exchange provided (equity securities) or market transactions for comparable securities and/or broker quotes (fixed income securities). Level 1—Investments in marketable equity securities within the NDT Fund are primarily investments in common stocks across a broad range of industries and sectors. Most equity securities are priced utilizing the principal market close price or, in some cases, midpoint, bid or ask price. Certain open-ended mutual funds with mainly short-term investments are valued based on unadjusted quoted prices in active markets. The Rabbi Trust equity index fund is valued based on quoted prices in an active market. Level 2—NDT and Rabbi Trust fixed income securities are limited to investment grade corporate bonds, collateralized mortgage obligations, asset backed securities and government obligations or Federal Agency asset-backed securities with a wide range of maturities. Since many fixed income securities do not trade on a daily basis, they are priced using an evaluated pricing methodology that varies by asset class and reflects observable market information such as the most recent exchange price or quoted bid for similar securities. Market-based standard inputs typically include benchmark yields, reported trades, broker/dealer quotes and issuer spreads. Certain short-term investments are valued using observable market prices or market parameters such as time-to-maturity, coupon rate, quality rating and current yield. (E) Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral received or posted that has been allocated to derivative positions, where the right of offset exists, has been offset in the Condensed Consolidated Balance Sheets. As of September 30, 2015 , net cash collateral (received) paid of $(58) million , was netted against the corresponding net derivative contract positions. Of the $(58) million as of September 30, 2015 , $(70) million of cash collateral was netted against assets, and $12 million was netted against liabilities. As of December 31, 2014 , net cash collateral (received) paid of $24 million , was netted against the corresponding net derivative contract positions. Of the $24 million as of December 31, 2014 , $(12) million of cash collateral was netted against assets, and $36 million was netted against liabilities. Additional Information Regarding Level 3 Measurements For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is categorized in Level 3. This includes derivatives valued using indicative price quotations for contracts with tenors that extend into periods with no observable pricing. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 because the model inputs generally are not observable. PSEG’s Risk Management Committee approves risk management policies and objectives for risk assessment, control and valuation, counterparty credit approval and the monitoring and reporting of risk exposures. The Risk Management Committee reports to the Audit Committee of the PSEG Board of Directors on the scope of the risk management activities and is responsible for approving all valuation procedures at PSEG. Forward price curves for the power market utilized by Power to manage the portfolio are maintained and reviewed by PSEG’s Enterprise Risk Management market pricing group and used for financial reporting purposes. PSEG considers credit and nonperformance risk in the valuation of derivative contracts categorized in Levels 2 and 3, including both historical and current market data, in its assessment of credit and nonperformance risk by counterparty. The impacts of credit and nonperformance risk were not material to the financial statements. For PSE&G and Power, natural gas supply contracts are measured at fair value using modeling techniques taking into account the current price of natural gas adjusted for appropriate risk factors, as applicable, and internal assumptions about transportation costs, and accordingly, the fair value measurements are classified in Level 3. The fair value of Power's electric load contracts in which load consumption may change hourly based on demand are measured using certain unobservable inputs, such as historic load variability and, accordingly, are categorized as Level 3. For Power, long-term electric capacity contracts are measured using capacity auction prices. If the fair value for the unobservable tenor is significant, then the entire capacity contract is categorized as Level 3. The following tables provide details surrounding significant Level 3 valuations as of September 30, 2015 and December 31, 2014 . Quantitative Information About Level 3 Fair Value Measurements Significant Fair Value as of Valuation Unobservable Commodity Level 3 Position September 30, 2015 Technique(s) Input Range Assets (Liabilities) Millions PSE&G Gas Natural Gas Supply Contracts $ 4 $ (7 ) Discounted Cash Flow Transportation Costs $0.60 to $0.90/dekatherm Total PSE&G $ 4 $ (7 ) Power Electricity Electric Load Contracts $ 4 $ — Discounted Cash flow Historic Load Variability 0% to +10% Other Various (A) 1 — Total Power $ 5 $ — Total PSEG $ 9 $ (7 ) Quantitative Information About Level 3 Fair Value Measurements Significant Fair Value as of Valuation Unobservable Commodity Level 3 Position December 31, 2014 Technique(s) Input Range Assets (Liabilities) Millions PSE&G Gas Natural Gas Supply Contracts $ 26 $ — Discounted Cash Flow Transportation Costs $0.70 to $1/dekatherm Total PSE&G $ 26 $ — Power Electricity Electric Load Contracts $ 12 $ (1 ) Discounted Cash Flow Historic Load Variability 0% to +10% Other Various (B) — — Total Power $ 12 $ (1 ) Total PSEG $ 38 $ (1 ) (A) Includes long-term electric positions which were immaterial as of September 30, 2015 . (B) Includes gas supply positions and long-term electric capacity positions which were immaterial as of December 31, 2014 . Significant unobservable inputs listed above would have a direct impact on the fair values of the above Level 3 instruments if they were adjusted. For gas supply contracts where PSE&G is a seller, an increase in gas transportation cost would increase the fair value. For energy-related contracts in cases where Power is a seller, an increase in either the power basis or the load variability or the longer-term gas basis amounts would decrease the fair value. A reconciliation of the beginning and ending balances of Level 3 derivative contracts and securities for the three months and nine months ended September 30, 2015 and September 30, 2014 , respectively, follows: Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis for the Three Months and Nine Months Ended September 30, 2015 Three Months Ended September 30, 2015 Total Gains or (Losses) Realized/Unrealized Description Balance as of July 1, 2015 Included in Income (A) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out Balance as of September 30, 2015 Millions PSEG Net Derivative Assets (Liabilities) $ 8 $ 4 $ (8 ) $ — $ (2 ) $ — $ 2 PSE&G Net Derivative Assets (Liabilities) $ 5 $ — $ (8 ) $ — $ — $ — $ (3 ) Power Net Derivative Assets (Liabilities) $ 3 $ 4 $ — $ — $ (2 ) $ — $ 5 Nine Months Ended September 30, 2015 Total Gains or (Losses) Realized/Unrealized Description Balance as of January 1, 2015 Included in Income (A) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out Balance as of September 30, 2015 Millions PSEG Net Derivative Assets (Liabilities) $ 37 $ 12 $ (29 ) $ — $ (18 ) $ — $ 2 PSE&G Net Derivative Assets (Liabilities) $ 26 $ — $ (29 ) $ — $ — $ — $ (3 ) Power Net Derivative Assets (Liabilities) $ 11 $ 12 $ — $ — $ (18 ) $ — $ 5 Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis for the Three Months and Nine Months Ended September 30, 2014 Three Months Ended September 30, 2014 Total Gains or (Losses) Realized/Unrealized Description Balance as of July 1, 2014 Included in Income (E) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out (D) Balance as of September 30, 2014 Millions PSEG Net Derivative Assets (Liabilities) $ 13 $ (8 ) $ (9 ) $ — $ (4 ) $ — $ (8 ) PSE&G Net Derivative Assets (Liabilities) $ 22 $ — $ (9 ) $ — $ — $ — $ 13 Power Net Derivative Assets (Liabilities) $ (9 ) $ (8 ) $ — $ — $ (4 ) $ — $ (21 ) Nine Months Ended September 30, 2014 Total Gains or (Losses) Realized/Unrealized Description Balance as of January 1, 2014 Included in Income (E) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out (D) Balance as of September 30, 2014 Millions PSEG Net Derivative Assets (Liabilities) $ 88 $ (66 ) $ (81 ) $ — $ 54 $ (3 ) $ (8 ) PSE&G Net Derivative Assets (Liabilities) $ 94 $ — $ (81 ) $ — $ — $ — $ 13 Power Net Derivative Assets (Liabilities) $ (6 ) $ (66 ) $ — $ — $ 54 $ (3 ) $ (21 ) (A) PSEG’s and Power’s gains and losses attributable to changes in net derivative assets and liabilities includes $4 million and $12 million in Operating Income for the three months and nine months ended September 30, 2015 , respectively. Of the $4 million in Operating Income, $3 million is unrealized. Of the $12 million in Operating Income, $(6) million is unrealized. (B) Mainly includes gains/losses on PSE&G’s derivative contracts that are not included in either earnings or Other Comprehensive Income, as they are deferred as a Regulatory Asset/Liability and are expected to be recovered from/returned to PSE&G’s customers. (C) Represents $(2) million and $(18) million in settlements for the three months and nine months ended September 30, 2015 . Includes $(4) million and $54 million in settlements for the three months and nine months ended September 30, 2014 . (D) There were no transfers among levels during the three months ended September 30, 2015 and 2014 and the nine months ended September 30, 2015 . During the nine months ended September 30, 2014 , $(3) million of net derivative assets/liabilities were transferred from Level 3 to Level 2 due to more observable pricing for the underlying securities. The transfers were recognized as of the beginning of the quarters in which the transfers first occurred as per PSEG's policy. (E) PSEG’s and Power’s gains and losses attributable to changes in net derivative assets and liabilities include $(8) million and $(66) million in Operating Income for the three months and nine months ended September 30, 2014 , respectively. Of the $(8) million in Operating Income, $(12) million is unrealized. Of the $(66) million in Operating Income, $(11) million is unrealized. As of September 30, 2015 , PSEG carried $2.3 billion of net assets that are measured at fair value on a recurring basis, of which $2 million of net assets were measured using unobservable inputs and classified as Level 3 within the fair value hierarchy. As of September 30, 2014 , PSEG carried $2.5 billion of net assets that are measured at fair value on a recurring basis, of which $8 million of net liabilities were measured using unobservable inputs and classified as Level 3 within the fair value hierarchy. Fair Value of Debt The estimated fair values were determined using the market quotations or values of instruments with similar terms, credit ratings, remaining maturities and redemptions as of September 30, 2015 and December 31, 2014 . As of As of September 30, 2015 December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Millions Long-Term Debt: PSEG (Parent) (A) $ 7 $ 11 $ 14 $ 22 PSE&G (B) 6,612 7,102 6,312 6,912 Transition Funding (PSE&G) (B) 68 69 251 261 Transition Funding II (PSE&G) (B) — — 8 8 Power - Recourse Debt (B) 2,544 2,856 2,543 2,930 Energy Holdings: Project Level, Non-Recourse Debt (C) 7 7 16 16 Total Long-Term Debt $ 9,238 $ 10,045 $ 9,144 $ 10,149 (A) Fair value represents net offsets to debt resulting from adjustments from interest rate swaps entered into to hedge certain debt at Power. Carrying amount represents such fair value reduced by the unamortized premium resulting from a debt exchange entered into between Power and Energy Holdings. (B) The debt fair valuation is based on the present value of each bond’s future cash flows. The discount rates used in the present value analysis are based on an estimate of new issue bond yields across the treasury curve. When a bond has embedded options, an interest rate model is used to reflect the impact of interest rate volatility into the analysis (primarily Level 2 measurements). (C) Non-recourse project debt is valued as equivalent to the amortized cost and is classified as a Level 3 measurement. |
PSE And G [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value Measurements | Fair Value Measurements Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Accounting guidance for fair value measurement emphasizes that fair value is a market-based measurement, not an entity-specific measurement, and establishes a fair value hierarchy that distinguishes between assumptions based on market data obtained from independent sources and those based on an entity’s own assumptions. The hierarchy prioritizes the inputs to fair value measurement into three levels: Level 1—measurements utilize quoted prices (unadjusted) in active markets for identical assets or liabilities that PSEG, PSE&G and Power have the ability to access. These consist primarily of listed equity securities and money market mutual funds. Level 2—measurements include quoted prices for similar assets and liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, and other observable inputs such as interest rates and yield curves that are observable at commonly quoted intervals. These consist primarily of non-exchange traded derivatives such as forward contracts or options and most fixed income securities. Level 3—measurements use unobservable inputs for assets or liabilities, based on the best information available and might include an entity’s own data and assumptions. In some valuations, the inputs used may fall into different levels of the hierarchy. In these cases, the financial instrument’s level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. As of September 30, 2015 , these consisted primarily of long-term gas supply contracts and certain electric load contracts. The following tables present information about PSEG’s, PSE&G’s and Power's respective assets and (liabilities) measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014 , including the fair value measurements and the levels of inputs used in determining those fair values. Amounts shown for PSEG include the amounts shown for PSE&G and Power. Recurring Fair Value Measurements as of September 30, 2015 Description Total Netting (E) Quoted Market Prices for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Millions PSEG Assets: Cash Equivalents (A) $ 226 $ — $ 226 $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 242 $ (461 ) $ — $ 694 $ 9 Interest Rate Swaps (C) $ 11 $ — $ — $ 11 $ — NDT Fund (D) Equity Securities $ 825 $ — $ 824 $ 1 $ — Debt Securities—Govt Obligations $ 454 $ — $ — $ 454 $ — Debt Securities—Other $ 401 $ — $ — $ 401 $ — Other Securities $ 35 $ — $ 35 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 20 $ — $ 20 $ — $ — Debt Securities—Govt Obligations $ 106 $ — $ — $ 106 $ — Debt Securities—Other $ 84 $ — $ — $ 84 $ — Other Securities $ 1 $ — $ 1 $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (93 ) $ 403 $ — $ (489 ) $ (7 ) PSE&G Assets: Cash Equivalents (A) $ — $ — $ — $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 4 $ — $ — $ — $ 4 Rabbi Trust (D) Equity Securities—Mutual Funds $ 4 $ — $ 4 $ — $ — Debt Securities—Govt Obligations $ 21 $ — $ — $ 21 $ — Debt Securities—Other $ 17 $ — $ — $ 17 $ — Other Securities $ — $ — $ — $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (7 ) $ — $ — $ — $ (7 ) Power Assets: Derivative Contracts: Energy-Related Contracts (B) $ 238 $ (461 ) $ — $ 694 $ 5 NDT Fund (D) Equity Securities $ 825 $ — $ 824 $ 1 $ — Debt Securities—Govt Obligations $ 454 $ — $ — $ 454 $ — Debt Securities—Other $ 401 $ — $ — $ 401 $ — Other Securities $ 35 $ — $ 35 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 26 $ — $ — $ 26 $ — Debt Securities—Other $ 21 $ — $ — $ 21 $ — Other Securities $ — $ — $ — $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (86 ) $ 403 $ — $ (489 ) $ — Recurring Fair Value Measurements as of December 31, 2014 Description Total Netting (E) Quoted Market Prices for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Millions PSEG Assets: Cash Equivalents (A) $ 365 $ — $ 365 $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 295 $ (517 ) $ — $ 774 $ 38 Interest Rate Swaps (C) $ 22 $ — $ — $ 22 $ — NDT Fund (D) Equity Securities $ 897 $ — $ 896 $ 1 $ — Debt Securities—Govt Obligations $ 438 $ — $ — $ 438 $ — Debt Securities—Other $ 339 $ — $ — $ 339 $ — Other Securities $ 106 $ — $ 106 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 23 $ — $ 23 $ — $ — Debt Securities—Govt Obligations $ 91 $ — $ — $ 91 $ — Debt Securities—Other $ 75 $ — $ — $ 75 $ — Other Securities $ 2 $ — $ — $ 2 $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (165 ) $ 541 $ — $ (705 ) $ (1 ) PSE&G Assets: Cash Equivalents (A) $ 294 $ — $ 294 $ — $ — Derivative Contracts: Energy Related Contracts (B) $ 26 $ — $ — $ — $ 26 Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 20 $ — $ — $ 20 $ — Debt Securities—Other $ 16 $ — $ — $ 16 $ — Other Securities $ — $ — $ — $ — $ — Power Assets: Derivative Contracts: Energy-Related Contracts (B) $ 269 $ (517 ) $ — $ 774 $ 12 NDT Fund (D) Equity Securities $ 897 $ — $ 896 $ 1 $ — Debt Securities—Govt Obligations $ 438 $ — $ — $ 438 $ — Debt Securities—Other $ 339 $ — $ — $ 339 $ — Other Securities $ 106 $ — $ 106 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 21 $ — $ — $ 21 $ — Debt Securities—Other $ 18 $ — $ — $ 18 $ — Other Securities $ 1 $ — $ — $ 1 $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (165 ) $ 541 $ — $ (705 ) $ (1 ) (A) Represents money market mutual funds. (B) Level 2—Fair values for energy-related contracts are obtained primarily using a market-based approach. Most derivative contracts (forward purchase or sale contracts and swaps) are valued using the average of the bid/ask midpoints from multiple broker or dealer quotes or auction prices. Prices used in the valuation process are also corroborated independently by management to determine that values are based on actual transaction data or, in the absence of transactions, bid and offers for the day. Examples may include certain exchange and non-exchange traded capacity and electricity contracts and natural gas physical or swap contracts based on market prices, basis adjustments and other premiums where adjustments and premiums are not considered significant to the overall inputs. Level 3—For energy-related contracts, which include more complex agreements where limited observable inputs or pricing information are available, modeling techniques are employed using assumptions reflective of contractual terms, current market rates, forward price curves, discount rates and risk factors, as applicable. Fair values of other energy contracts may be based on broker quotes that we cannot corroborate with actual market transaction data. (C) Interest rate swaps are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment. (D) The NDT Fund maintains investments in various equity and fixed income securities classified as “available for sale.” The Rabbi Trust maintains investments in an S&P 500 index fund and various fixed income securities classified as “available for sale.” These securities are generally valued with prices that are either exchange provided (equity securities) or market transactions for comparable securities and/or broker quotes (fixed income securities). Level 1—Investments in marketable equity securities within the NDT Fund are primarily investments in common stocks across a broad range of industries and sectors. Most equity securities are priced utilizing the principal market close price or, in some cases, midpoint, bid or ask price. Certain open-ended mutual funds with mainly short-term investments are valued based on unadjusted quoted prices in active markets. The Rabbi Trust equity index fund is valued based on quoted prices in an active market. Level 2—NDT and Rabbi Trust fixed income securities are limited to investment grade corporate bonds, collateralized mortgage obligations, asset backed securities and government obligations or Federal Agency asset-backed securities with a wide range of maturities. Since many fixed income securities do not trade on a daily basis, they are priced using an evaluated pricing methodology that varies by asset class and reflects observable market information such as the most recent exchange price or quoted bid for similar securities. Market-based standard inputs typically include benchmark yields, reported trades, broker/dealer quotes and issuer spreads. Certain short-term investments are valued using observable market prices or market parameters such as time-to-maturity, coupon rate, quality rating and current yield. (E) Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral received or posted that has been allocated to derivative positions, where the right of offset exists, has been offset in the Condensed Consolidated Balance Sheets. As of September 30, 2015 , net cash collateral (received) paid of $(58) million , was netted against the corresponding net derivative contract positions. Of the $(58) million as of September 30, 2015 , $(70) million of cash collateral was netted against assets, and $12 million was netted against liabilities. As of December 31, 2014 , net cash collateral (received) paid of $24 million , was netted against the corresponding net derivative contract positions. Of the $24 million as of December 31, 2014 , $(12) million of cash collateral was netted against assets, and $36 million was netted against liabilities. Additional Information Regarding Level 3 Measurements For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is categorized in Level 3. This includes derivatives valued using indicative price quotations for contracts with tenors that extend into periods with no observable pricing. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 because the model inputs generally are not observable. PSEG’s Risk Management Committee approves risk management policies and objectives for risk assessment, control and valuation, counterparty credit approval and the monitoring and reporting of risk exposures. The Risk Management Committee reports to the Audit Committee of the PSEG Board of Directors on the scope of the risk management activities and is responsible for approving all valuation procedures at PSEG. Forward price curves for the power market utilized by Power to manage the portfolio are maintained and reviewed by PSEG’s Enterprise Risk Management market pricing group and used for financial reporting purposes. PSEG considers credit and nonperformance risk in the valuation of derivative contracts categorized in Levels 2 and 3, including both historical and current market data, in its assessment of credit and nonperformance risk by counterparty. The impacts of credit and nonperformance risk were not material to the financial statements. For PSE&G and Power, natural gas supply contracts are measured at fair value using modeling techniques taking into account the current price of natural gas adjusted for appropriate risk factors, as applicable, and internal assumptions about transportation costs, and accordingly, the fair value measurements are classified in Level 3. The fair value of Power's electric load contracts in which load consumption may change hourly based on demand are measured using certain unobservable inputs, such as historic load variability and, accordingly, are categorized as Level 3. For Power, long-term electric capacity contracts are measured using capacity auction prices. If the fair value for the unobservable tenor is significant, then the entire capacity contract is categorized as Level 3. The following tables provide details surrounding significant Level 3 valuations as of September 30, 2015 and December 31, 2014 . Quantitative Information About Level 3 Fair Value Measurements Significant Fair Value as of Valuation Unobservable Commodity Level 3 Position September 30, 2015 Technique(s) Input Range Assets (Liabilities) Millions PSE&G Gas Natural Gas Supply Contracts $ 4 $ (7 ) Discounted Cash Flow Transportation Costs $0.60 to $0.90/dekatherm Total PSE&G $ 4 $ (7 ) Power Electricity Electric Load Contracts $ 4 $ — Discounted Cash flow Historic Load Variability 0% to +10% Other Various (A) 1 — Total Power $ 5 $ — Total PSEG $ 9 $ (7 ) Quantitative Information About Level 3 Fair Value Measurements Significant Fair Value as of Valuation Unobservable Commodity Level 3 Position December 31, 2014 Technique(s) Input Range Assets (Liabilities) Millions PSE&G Gas Natural Gas Supply Contracts $ 26 $ — Discounted Cash Flow Transportation Costs $0.70 to $1/dekatherm Total PSE&G $ 26 $ — Power Electricity Electric Load Contracts $ 12 $ (1 ) Discounted Cash Flow Historic Load Variability 0% to +10% Other Various (B) — — Total Power $ 12 $ (1 ) Total PSEG $ 38 $ (1 ) (A) Includes long-term electric positions which were immaterial as of September 30, 2015 . (B) Includes gas supply positions and long-term electric capacity positions which were immaterial as of December 31, 2014 . Significant unobservable inputs listed above would have a direct impact on the fair values of the above Level 3 instruments if they were adjusted. For gas supply contracts where PSE&G is a seller, an increase in gas transportation cost would increase the fair value. For energy-related contracts in cases where Power is a seller, an increase in either the power basis or the load variability or the longer-term gas basis amounts would decrease the fair value. A reconciliation of the beginning and ending balances of Level 3 derivative contracts and securities for the three months and nine months ended September 30, 2015 and September 30, 2014 , respectively, follows: Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis for the Three Months and Nine Months Ended September 30, 2015 Three Months Ended September 30, 2015 Total Gains or (Losses) Realized/Unrealized Description Balance as of July 1, 2015 Included in Income (A) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out Balance as of September 30, 2015 Millions PSEG Net Derivative Assets (Liabilities) $ 8 $ 4 $ (8 ) $ — $ (2 ) $ — $ 2 PSE&G Net Derivative Assets (Liabilities) $ 5 $ — $ (8 ) $ — $ — $ — $ (3 ) Power Net Derivative Assets (Liabilities) $ 3 $ 4 $ — $ — $ (2 ) $ — $ 5 Nine Months Ended September 30, 2015 Total Gains or (Losses) Realized/Unrealized Description Balance as of January 1, 2015 Included in Income (A) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out Balance as of September 30, 2015 Millions PSEG Net Derivative Assets (Liabilities) $ 37 $ 12 $ (29 ) $ — $ (18 ) $ — $ 2 PSE&G Net Derivative Assets (Liabilities) $ 26 $ — $ (29 ) $ — $ — $ — $ (3 ) Power Net Derivative Assets (Liabilities) $ 11 $ 12 $ — $ — $ (18 ) $ — $ 5 Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis for the Three Months and Nine Months Ended September 30, 2014 Three Months Ended September 30, 2014 Total Gains or (Losses) Realized/Unrealized Description Balance as of July 1, 2014 Included in Income (E) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out (D) Balance as of September 30, 2014 Millions PSEG Net Derivative Assets (Liabilities) $ 13 $ (8 ) $ (9 ) $ — $ (4 ) $ — $ (8 ) PSE&G Net Derivative Assets (Liabilities) $ 22 $ — $ (9 ) $ — $ — $ — $ 13 Power Net Derivative Assets (Liabilities) $ (9 ) $ (8 ) $ — $ — $ (4 ) $ — $ (21 ) Nine Months Ended September 30, 2014 Total Gains or (Losses) Realized/Unrealized Description Balance as of January 1, 2014 Included in Income (E) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out (D) Balance as of September 30, 2014 Millions PSEG Net Derivative Assets (Liabilities) $ 88 $ (66 ) $ (81 ) $ — $ 54 $ (3 ) $ (8 ) PSE&G Net Derivative Assets (Liabilities) $ 94 $ — $ (81 ) $ — $ — $ — $ 13 Power Net Derivative Assets (Liabilities) $ (6 ) $ (66 ) $ — $ — $ 54 $ (3 ) $ (21 ) (A) PSEG’s and Power’s gains and losses attributable to changes in net derivative assets and liabilities includes $4 million and $12 million in Operating Income for the three months and nine months ended September 30, 2015 , respectively. Of the $4 million in Operating Income, $3 million is unrealized. Of the $12 million in Operating Income, $(6) million is unrealized. (B) Mainly includes gains/losses on PSE&G’s derivative contracts that are not included in either earnings or Other Comprehensive Income, as they are deferred as a Regulatory Asset/Liability and are expected to be recovered from/returned to PSE&G’s customers. (C) Represents $(2) million and $(18) million in settlements for the three months and nine months ended September 30, 2015 . Includes $(4) million and $54 million in settlements for the three months and nine months ended September 30, 2014 . (D) There were no transfers among levels during the three months ended September 30, 2015 and 2014 and the nine months ended September 30, 2015 . During the nine months ended September 30, 2014 , $(3) million of net derivative assets/liabilities were transferred from Level 3 to Level 2 due to more observable pricing for the underlying securities. The transfers were recognized as of the beginning of the quarters in which the transfers first occurred as per PSEG's policy. (E) PSEG’s and Power’s gains and losses attributable to changes in net derivative assets and liabilities include $(8) million and $(66) million in Operating Income for the three months and nine months ended September 30, 2014 , respectively. Of the $(8) million in Operating Income, $(12) million is unrealized. Of the $(66) million in Operating Income, $(11) million is unrealized. As of September 30, 2015 , PSEG carried $2.3 billion of net assets that are measured at fair value on a recurring basis, of which $2 million of net assets were measured using unobservable inputs and classified as Level 3 within the fair value hierarchy. As of September 30, 2014 , PSEG carried $2.5 billion of net assets that are measured at fair value on a recurring basis, of which $8 million of net liabilities were measured using unobservable inputs and classified as Level 3 within the fair value hierarchy. Fair Value of Debt The estimated fair values were determined using the market quotations or values of instruments with similar terms, credit ratings, remaining maturities and redemptions as of September 30, 2015 and December 31, 2014 . As of As of September 30, 2015 December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Millions Long-Term Debt: PSEG (Parent) (A) $ 7 $ 11 $ 14 $ 22 PSE&G (B) 6,612 7,102 6,312 6,912 Transition Funding (PSE&G) (B) 68 69 251 261 Transition Funding II (PSE&G) (B) — — 8 8 Power - Recourse Debt (B) 2,544 2,856 2,543 2,930 Energy Holdings: Project Level, Non-Recourse Debt (C) 7 7 16 16 Total Long-Term Debt $ 9,238 $ 10,045 $ 9,144 $ 10,149 (A) Fair value represents net offsets to debt resulting from adjustments from interest rate swaps entered into to hedge certain debt at Power. Carrying amount represents such fair value reduced by the unamortized premium resulting from a debt exchange entered into between Power and Energy Holdings. (B) The debt fair valuation is based on the present value of each bond’s future cash flows. The discount rates used in the present value analysis are based on an estimate of new issue bond yields across the treasury curve. When a bond has embedded options, an interest rate model is used to reflect the impact of interest rate volatility into the analysis (primarily Level 2 measurements). (C) Non-recourse project debt is valued as equivalent to the amortized cost and is classified as a Level 3 measurement. |
Power [Member] | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |
Fair Value Measurements | Fair Value Measurements Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Accounting guidance for fair value measurement emphasizes that fair value is a market-based measurement, not an entity-specific measurement, and establishes a fair value hierarchy that distinguishes between assumptions based on market data obtained from independent sources and those based on an entity’s own assumptions. The hierarchy prioritizes the inputs to fair value measurement into three levels: Level 1—measurements utilize quoted prices (unadjusted) in active markets for identical assets or liabilities that PSEG, PSE&G and Power have the ability to access. These consist primarily of listed equity securities and money market mutual funds. Level 2—measurements include quoted prices for similar assets and liabilities in active markets, quoted prices for identical or similar assets or liabilities in markets that are not active, and other observable inputs such as interest rates and yield curves that are observable at commonly quoted intervals. These consist primarily of non-exchange traded derivatives such as forward contracts or options and most fixed income securities. Level 3—measurements use unobservable inputs for assets or liabilities, based on the best information available and might include an entity’s own data and assumptions. In some valuations, the inputs used may fall into different levels of the hierarchy. In these cases, the financial instrument’s level within the fair value hierarchy is based on the lowest level of input that is significant to the fair value measurement. As of September 30, 2015 , these consisted primarily of long-term gas supply contracts and certain electric load contracts. The following tables present information about PSEG’s, PSE&G’s and Power's respective assets and (liabilities) measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014 , including the fair value measurements and the levels of inputs used in determining those fair values. Amounts shown for PSEG include the amounts shown for PSE&G and Power. Recurring Fair Value Measurements as of September 30, 2015 Description Total Netting (E) Quoted Market Prices for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Millions PSEG Assets: Cash Equivalents (A) $ 226 $ — $ 226 $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 242 $ (461 ) $ — $ 694 $ 9 Interest Rate Swaps (C) $ 11 $ — $ — $ 11 $ — NDT Fund (D) Equity Securities $ 825 $ — $ 824 $ 1 $ — Debt Securities—Govt Obligations $ 454 $ — $ — $ 454 $ — Debt Securities—Other $ 401 $ — $ — $ 401 $ — Other Securities $ 35 $ — $ 35 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 20 $ — $ 20 $ — $ — Debt Securities—Govt Obligations $ 106 $ — $ — $ 106 $ — Debt Securities—Other $ 84 $ — $ — $ 84 $ — Other Securities $ 1 $ — $ 1 $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (93 ) $ 403 $ — $ (489 ) $ (7 ) PSE&G Assets: Cash Equivalents (A) $ — $ — $ — $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 4 $ — $ — $ — $ 4 Rabbi Trust (D) Equity Securities—Mutual Funds $ 4 $ — $ 4 $ — $ — Debt Securities—Govt Obligations $ 21 $ — $ — $ 21 $ — Debt Securities—Other $ 17 $ — $ — $ 17 $ — Other Securities $ — $ — $ — $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (7 ) $ — $ — $ — $ (7 ) Power Assets: Derivative Contracts: Energy-Related Contracts (B) $ 238 $ (461 ) $ — $ 694 $ 5 NDT Fund (D) Equity Securities $ 825 $ — $ 824 $ 1 $ — Debt Securities—Govt Obligations $ 454 $ — $ — $ 454 $ — Debt Securities—Other $ 401 $ — $ — $ 401 $ — Other Securities $ 35 $ — $ 35 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 26 $ — $ — $ 26 $ — Debt Securities—Other $ 21 $ — $ — $ 21 $ — Other Securities $ — $ — $ — $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (86 ) $ 403 $ — $ (489 ) $ — Recurring Fair Value Measurements as of December 31, 2014 Description Total Netting (E) Quoted Market Prices for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Millions PSEG Assets: Cash Equivalents (A) $ 365 $ — $ 365 $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 295 $ (517 ) $ — $ 774 $ 38 Interest Rate Swaps (C) $ 22 $ — $ — $ 22 $ — NDT Fund (D) Equity Securities $ 897 $ — $ 896 $ 1 $ — Debt Securities—Govt Obligations $ 438 $ — $ — $ 438 $ — Debt Securities—Other $ 339 $ — $ — $ 339 $ — Other Securities $ 106 $ — $ 106 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 23 $ — $ 23 $ — $ — Debt Securities—Govt Obligations $ 91 $ — $ — $ 91 $ — Debt Securities—Other $ 75 $ — $ — $ 75 $ — Other Securities $ 2 $ — $ — $ 2 $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (165 ) $ 541 $ — $ (705 ) $ (1 ) PSE&G Assets: Cash Equivalents (A) $ 294 $ — $ 294 $ — $ — Derivative Contracts: Energy Related Contracts (B) $ 26 $ — $ — $ — $ 26 Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 20 $ — $ — $ 20 $ — Debt Securities—Other $ 16 $ — $ — $ 16 $ — Other Securities $ — $ — $ — $ — $ — Power Assets: Derivative Contracts: Energy-Related Contracts (B) $ 269 $ (517 ) $ — $ 774 $ 12 NDT Fund (D) Equity Securities $ 897 $ — $ 896 $ 1 $ — Debt Securities—Govt Obligations $ 438 $ — $ — $ 438 $ — Debt Securities—Other $ 339 $ — $ — $ 339 $ — Other Securities $ 106 $ — $ 106 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 21 $ — $ — $ 21 $ — Debt Securities—Other $ 18 $ — $ — $ 18 $ — Other Securities $ 1 $ — $ — $ 1 $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (165 ) $ 541 $ — $ (705 ) $ (1 ) (A) Represents money market mutual funds. (B) Level 2—Fair values for energy-related contracts are obtained primarily using a market-based approach. Most derivative contracts (forward purchase or sale contracts and swaps) are valued using the average of the bid/ask midpoints from multiple broker or dealer quotes or auction prices. Prices used in the valuation process are also corroborated independently by management to determine that values are based on actual transaction data or, in the absence of transactions, bid and offers for the day. Examples may include certain exchange and non-exchange traded capacity and electricity contracts and natural gas physical or swap contracts based on market prices, basis adjustments and other premiums where adjustments and premiums are not considered significant to the overall inputs. Level 3—For energy-related contracts, which include more complex agreements where limited observable inputs or pricing information are available, modeling techniques are employed using assumptions reflective of contractual terms, current market rates, forward price curves, discount rates and risk factors, as applicable. Fair values of other energy contracts may be based on broker quotes that we cannot corroborate with actual market transaction data. (C) Interest rate swaps are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment. (D) The NDT Fund maintains investments in various equity and fixed income securities classified as “available for sale.” The Rabbi Trust maintains investments in an S&P 500 index fund and various fixed income securities classified as “available for sale.” These securities are generally valued with prices that are either exchange provided (equity securities) or market transactions for comparable securities and/or broker quotes (fixed income securities). Level 1—Investments in marketable equity securities within the NDT Fund are primarily investments in common stocks across a broad range of industries and sectors. Most equity securities are priced utilizing the principal market close price or, in some cases, midpoint, bid or ask price. Certain open-ended mutual funds with mainly short-term investments are valued based on unadjusted quoted prices in active markets. The Rabbi Trust equity index fund is valued based on quoted prices in an active market. Level 2—NDT and Rabbi Trust fixed income securities are limited to investment grade corporate bonds, collateralized mortgage obligations, asset backed securities and government obligations or Federal Agency asset-backed securities with a wide range of maturities. Since many fixed income securities do not trade on a daily basis, they are priced using an evaluated pricing methodology that varies by asset class and reflects observable market information such as the most recent exchange price or quoted bid for similar securities. Market-based standard inputs typically include benchmark yields, reported trades, broker/dealer quotes and issuer spreads. Certain short-term investments are valued using observable market prices or market parameters such as time-to-maturity, coupon rate, quality rating and current yield. (E) Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral received or posted that has been allocated to derivative positions, where the right of offset exists, has been offset in the Condensed Consolidated Balance Sheets. As of September 30, 2015 , net cash collateral (received) paid of $(58) million , was netted against the corresponding net derivative contract positions. Of the $(58) million as of September 30, 2015 , $(70) million of cash collateral was netted against assets, and $12 million was netted against liabilities. As of December 31, 2014 , net cash collateral (received) paid of $24 million , was netted against the corresponding net derivative contract positions. Of the $24 million as of December 31, 2014 , $(12) million of cash collateral was netted against assets, and $36 million was netted against liabilities. Additional Information Regarding Level 3 Measurements For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is categorized in Level 3. This includes derivatives valued using indicative price quotations for contracts with tenors that extend into periods with no observable pricing. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility and contract duration. Such instruments are categorized in Level 3 because the model inputs generally are not observable. PSEG’s Risk Management Committee approves risk management policies and objectives for risk assessment, control and valuation, counterparty credit approval and the monitoring and reporting of risk exposures. The Risk Management Committee reports to the Audit Committee of the PSEG Board of Directors on the scope of the risk management activities and is responsible for approving all valuation procedures at PSEG. Forward price curves for the power market utilized by Power to manage the portfolio are maintained and reviewed by PSEG’s Enterprise Risk Management market pricing group and used for financial reporting purposes. PSEG considers credit and nonperformance risk in the valuation of derivative contracts categorized in Levels 2 and 3, including both historical and current market data, in its assessment of credit and nonperformance risk by counterparty. The impacts of credit and nonperformance risk were not material to the financial statements. For PSE&G and Power, natural gas supply contracts are measured at fair value using modeling techniques taking into account the current price of natural gas adjusted for appropriate risk factors, as applicable, and internal assumptions about transportation costs, and accordingly, the fair value measurements are classified in Level 3. The fair value of Power's electric load contracts in which load consumption may change hourly based on demand are measured using certain unobservable inputs, such as historic load variability and, accordingly, are categorized as Level 3. For Power, long-term electric capacity contracts are measured using capacity auction prices. If the fair value for the unobservable tenor is significant, then the entire capacity contract is categorized as Level 3. The following tables provide details surrounding significant Level 3 valuations as of September 30, 2015 and December 31, 2014 . Quantitative Information About Level 3 Fair Value Measurements Significant Fair Value as of Valuation Unobservable Commodity Level 3 Position September 30, 2015 Technique(s) Input Range Assets (Liabilities) Millions PSE&G Gas Natural Gas Supply Contracts $ 4 $ (7 ) Discounted Cash Flow Transportation Costs $0.60 to $0.90/dekatherm Total PSE&G $ 4 $ (7 ) Power Electricity Electric Load Contracts $ 4 $ — Discounted Cash flow Historic Load Variability 0% to +10% Other Various (A) 1 — Total Power $ 5 $ — Total PSEG $ 9 $ (7 ) Quantitative Information About Level 3 Fair Value Measurements Significant Fair Value as of Valuation Unobservable Commodity Level 3 Position December 31, 2014 Technique(s) Input Range Assets (Liabilities) Millions PSE&G Gas Natural Gas Supply Contracts $ 26 $ — Discounted Cash Flow Transportation Costs $0.70 to $1/dekatherm Total PSE&G $ 26 $ — Power Electricity Electric Load Contracts $ 12 $ (1 ) Discounted Cash Flow Historic Load Variability 0% to +10% Other Various (B) — — Total Power $ 12 $ (1 ) Total PSEG $ 38 $ (1 ) (A) Includes long-term electric positions which were immaterial as of September 30, 2015 . (B) Includes gas supply positions and long-term electric capacity positions which were immaterial as of December 31, 2014 . Significant unobservable inputs listed above would have a direct impact on the fair values of the above Level 3 instruments if they were adjusted. For gas supply contracts where PSE&G is a seller, an increase in gas transportation cost would increase the fair value. For energy-related contracts in cases where Power is a seller, an increase in either the power basis or the load variability or the longer-term gas basis amounts would decrease the fair value. A reconciliation of the beginning and ending balances of Level 3 derivative contracts and securities for the three months and nine months ended September 30, 2015 and September 30, 2014 , respectively, follows: Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis for the Three Months and Nine Months Ended September 30, 2015 Three Months Ended September 30, 2015 Total Gains or (Losses) Realized/Unrealized Description Balance as of July 1, 2015 Included in Income (A) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out Balance as of September 30, 2015 Millions PSEG Net Derivative Assets (Liabilities) $ 8 $ 4 $ (8 ) $ — $ (2 ) $ — $ 2 PSE&G Net Derivative Assets (Liabilities) $ 5 $ — $ (8 ) $ — $ — $ — $ (3 ) Power Net Derivative Assets (Liabilities) $ 3 $ 4 $ — $ — $ (2 ) $ — $ 5 Nine Months Ended September 30, 2015 Total Gains or (Losses) Realized/Unrealized Description Balance as of January 1, 2015 Included in Income (A) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out Balance as of September 30, 2015 Millions PSEG Net Derivative Assets (Liabilities) $ 37 $ 12 $ (29 ) $ — $ (18 ) $ — $ 2 PSE&G Net Derivative Assets (Liabilities) $ 26 $ — $ (29 ) $ — $ — $ — $ (3 ) Power Net Derivative Assets (Liabilities) $ 11 $ 12 $ — $ — $ (18 ) $ — $ 5 Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis for the Three Months and Nine Months Ended September 30, 2014 Three Months Ended September 30, 2014 Total Gains or (Losses) Realized/Unrealized Description Balance as of July 1, 2014 Included in Income (E) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out (D) Balance as of September 30, 2014 Millions PSEG Net Derivative Assets (Liabilities) $ 13 $ (8 ) $ (9 ) $ — $ (4 ) $ — $ (8 ) PSE&G Net Derivative Assets (Liabilities) $ 22 $ — $ (9 ) $ — $ — $ — $ 13 Power Net Derivative Assets (Liabilities) $ (9 ) $ (8 ) $ — $ — $ (4 ) $ — $ (21 ) Nine Months Ended September 30, 2014 Total Gains or (Losses) Realized/Unrealized Description Balance as of January 1, 2014 Included in Income (E) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out (D) Balance as of September 30, 2014 Millions PSEG Net Derivative Assets (Liabilities) $ 88 $ (66 ) $ (81 ) $ — $ 54 $ (3 ) $ (8 ) PSE&G Net Derivative Assets (Liabilities) $ 94 $ — $ (81 ) $ — $ — $ — $ 13 Power Net Derivative Assets (Liabilities) $ (6 ) $ (66 ) $ — $ — $ 54 $ (3 ) $ (21 ) (A) PSEG’s and Power’s gains and losses attributable to changes in net derivative assets and liabilities includes $4 million and $12 million in Operating Income for the three months and nine months ended September 30, 2015 , respectively. Of the $4 million in Operating Income, $3 million is unrealized. Of the $12 million in Operating Income, $(6) million is unrealized. (B) Mainly includes gains/losses on PSE&G’s derivative contracts that are not included in either earnings or Other Comprehensive Income, as they are deferred as a Regulatory Asset/Liability and are expected to be recovered from/returned to PSE&G’s customers. (C) Represents $(2) million and $(18) million in settlements for the three months and nine months ended September 30, 2015 . Includes $(4) million and $54 million in settlements for the three months and nine months ended September 30, 2014 . (D) There were no transfers among levels during the three months ended September 30, 2015 and 2014 and the nine months ended September 30, 2015 . During the nine months ended September 30, 2014 , $(3) million of net derivative assets/liabilities were transferred from Level 3 to Level 2 due to more observable pricing for the underlying securities. The transfers were recognized as of the beginning of the quarters in which the transfers first occurred as per PSEG's policy. (E) PSEG’s and Power’s gains and losses attributable to changes in net derivative assets and liabilities include $(8) million and $(66) million in Operating Income for the three months and nine months ended September 30, 2014 , respectively. Of the $(8) million in Operating Income, $(12) million is unrealized. Of the $(66) million in Operating Income, $(11) million is unrealized. As of September 30, 2015 , PSEG carried $2.3 billion of net assets that are measured at fair value on a recurring basis, of which $2 million of net assets were measured using unobservable inputs and classified as Level 3 within the fair value hierarchy. As of September 30, 2014 , PSEG carried $2.5 billion of net assets that are measured at fair value on a recurring basis, of which $8 million of net liabilities were measured using unobservable inputs and classified as Level 3 within the fair value hierarchy. Fair Value of Debt The estimated fair values were determined using the market quotations or values of instruments with similar terms, credit ratings, remaining maturities and redemptions as of September 30, 2015 and December 31, 2014 . As of As of September 30, 2015 December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Millions Long-Term Debt: PSEG (Parent) (A) $ 7 $ 11 $ 14 $ 22 PSE&G (B) 6,612 7,102 6,312 6,912 Transition Funding (PSE&G) (B) 68 69 251 261 Transition Funding II (PSE&G) (B) — — 8 8 Power - Recourse Debt (B) 2,544 2,856 2,543 2,930 Energy Holdings: Project Level, Non-Recourse Debt (C) 7 7 16 16 Total Long-Term Debt $ 9,238 $ 10,045 $ 9,144 $ 10,149 (A) Fair value represents net offsets to debt resulting from adjustments from interest rate swaps entered into to hedge certain debt at Power. Carrying amount represents such fair value reduced by the unamortized premium resulting from a debt exchange entered into between Power and Energy Holdings. (B) The debt fair valuation is based on the present value of each bond’s future cash flows. The discount rates used in the present value analysis are based on an estimate of new issue bond yields across the treasury curve. When a bond has embedded options, an interest rate model is used to reflect the impact of interest rate volatility into the analysis (primarily Level 2 measurements). (C) Non-recourse project debt is valued as equivalent to the amortized cost and is classified as a Level 3 measurement. |
Other Income and Deductions
Other Income and Deductions | 9 Months Ended |
Sep. 30, 2015 | |
Component of Other Income [Line Items] | |
Other Income and Deductions | Other Income and Deductions Other Income PSE&G Power Other (A) Consolidated Millions Three Months Ended September 30, 2015 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 24 $ — $ 24 Allowance for Funds Used During Construction 14 — — 14 Solar Loan Interest 6 — — 6 Other 2 1 — 3 Total Other Income $ 22 $ 25 $ — $ 47 Nine Months Ended September 30, 2015 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 78 $ — $ 78 Allowance for Funds Used During Construction 36 — — 36 Solar Loan Interest 18 — — 18 Gain on Insurance Recovery — 28 — 28 Other 5 3 3 11 Total Other Income $ 59 $ 109 $ 3 $ 171 Three Months Ended September 30, 2014 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 55 $ — $ 55 Allowance for Funds Used During Construction 8 — — 8 Solar Loan Interest 6 — — 6 Other 2 1 3 6 Total Other Income $ 16 $ 56 $ 3 $ 75 Nine Months Ended September 30, 2014 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 133 $ — $ 133 Allowance for Funds Used During Construction 21 — — 21 Solar Loan Interest 18 — — 18 Other 5 2 6 13 Total Other Income $ 44 $ 135 $ 6 $ 185 Other Deductions PSE&G Power Other (A) Consolidated Millions Three Months Ended September 30, 2015 NDT Fund Realized Losses and Expenses $ — $ 13 $ — $ 13 Other — 1 — 1 Total Other Deductions $ — $ 14 $ — $ 14 Nine Months Ended September 30, 2015 NDT Fund Realized Losses and Expenses $ — $ 30 $ — $ 30 Other 2 2 2 6 Total Other Deductions $ 2 $ 32 $ 2 $ 36 Three Months Ended September 30, 2014 NDT Fund Realized Losses and Expenses $ — $ 4 $ — $ 4 Other 2 2 1 5 Total Other Deductions $ 2 $ 6 $ 1 $ 9 Nine Months Ended September 30, 2014 NDT Fund Realized Losses and Expenses $ — $ 18 $ — $ 18 Other 3 7 3 13 Total Other Deductions $ 3 $ 25 $ 3 $ 31 (A) Other consists of activity at PSEG (as parent company), Energy Holdings, Services, PSEG LI and intercompany eliminations. |
PSE And G [Member] | |
Component of Other Income [Line Items] | |
Other Income and Deductions | Other Income and Deductions Other Income PSE&G Power Other (A) Consolidated Millions Three Months Ended September 30, 2015 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 24 $ — $ 24 Allowance for Funds Used During Construction 14 — — 14 Solar Loan Interest 6 — — 6 Other 2 1 — 3 Total Other Income $ 22 $ 25 $ — $ 47 Nine Months Ended September 30, 2015 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 78 $ — $ 78 Allowance for Funds Used During Construction 36 — — 36 Solar Loan Interest 18 — — 18 Gain on Insurance Recovery — 28 — 28 Other 5 3 3 11 Total Other Income $ 59 $ 109 $ 3 $ 171 Three Months Ended September 30, 2014 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 55 $ — $ 55 Allowance for Funds Used During Construction 8 — — 8 Solar Loan Interest 6 — — 6 Other 2 1 3 6 Total Other Income $ 16 $ 56 $ 3 $ 75 Nine Months Ended September 30, 2014 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 133 $ — $ 133 Allowance for Funds Used During Construction 21 — — 21 Solar Loan Interest 18 — — 18 Other 5 2 6 13 Total Other Income $ 44 $ 135 $ 6 $ 185 Other Deductions PSE&G Power Other (A) Consolidated Millions Three Months Ended September 30, 2015 NDT Fund Realized Losses and Expenses $ — $ 13 $ — $ 13 Other — 1 — 1 Total Other Deductions $ — $ 14 $ — $ 14 Nine Months Ended September 30, 2015 NDT Fund Realized Losses and Expenses $ — $ 30 $ — $ 30 Other 2 2 2 6 Total Other Deductions $ 2 $ 32 $ 2 $ 36 Three Months Ended September 30, 2014 NDT Fund Realized Losses and Expenses $ — $ 4 $ — $ 4 Other 2 2 1 5 Total Other Deductions $ 2 $ 6 $ 1 $ 9 Nine Months Ended September 30, 2014 NDT Fund Realized Losses and Expenses $ — $ 18 $ — $ 18 Other 3 7 3 13 Total Other Deductions $ 3 $ 25 $ 3 $ 31 (A) Other consists of activity at PSEG (as parent company), Energy Holdings, Services, PSEG LI and intercompany eliminations. |
Power [Member] | |
Component of Other Income [Line Items] | |
Other Income and Deductions | Other Income and Deductions Other Income PSE&G Power Other (A) Consolidated Millions Three Months Ended September 30, 2015 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 24 $ — $ 24 Allowance for Funds Used During Construction 14 — — 14 Solar Loan Interest 6 — — 6 Other 2 1 — 3 Total Other Income $ 22 $ 25 $ — $ 47 Nine Months Ended September 30, 2015 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 78 $ — $ 78 Allowance for Funds Used During Construction 36 — — 36 Solar Loan Interest 18 — — 18 Gain on Insurance Recovery — 28 — 28 Other 5 3 3 11 Total Other Income $ 59 $ 109 $ 3 $ 171 Three Months Ended September 30, 2014 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 55 $ — $ 55 Allowance for Funds Used During Construction 8 — — 8 Solar Loan Interest 6 — — 6 Other 2 1 3 6 Total Other Income $ 16 $ 56 $ 3 $ 75 Nine Months Ended September 30, 2014 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 133 $ — $ 133 Allowance for Funds Used During Construction 21 — — 21 Solar Loan Interest 18 — — 18 Other 5 2 6 13 Total Other Income $ 44 $ 135 $ 6 $ 185 Other Deductions PSE&G Power Other (A) Consolidated Millions Three Months Ended September 30, 2015 NDT Fund Realized Losses and Expenses $ — $ 13 $ — $ 13 Other — 1 — 1 Total Other Deductions $ — $ 14 $ — $ 14 Nine Months Ended September 30, 2015 NDT Fund Realized Losses and Expenses $ — $ 30 $ — $ 30 Other 2 2 2 6 Total Other Deductions $ 2 $ 32 $ 2 $ 36 Three Months Ended September 30, 2014 NDT Fund Realized Losses and Expenses $ — $ 4 $ — $ 4 Other 2 2 1 5 Total Other Deductions $ 2 $ 6 $ 1 $ 9 Nine Months Ended September 30, 2014 NDT Fund Realized Losses and Expenses $ — $ 18 $ — $ 18 Other 3 7 3 13 Total Other Deductions $ 3 $ 25 $ 3 $ 31 (A) Other consists of activity at PSEG (as parent company), Energy Holdings, Services, PSEG LI and intercompany eliminations. |
Income Taxes
Income Taxes | 9 Months Ended |
Sep. 30, 2015 | |
Income Taxes [Line Items] | |
Income Taxes | Income Taxes PSEG’s, PSE&G’s and Power's effective tax rates for the three months and nine months ended September 30, 2015 and 2014 were as follows: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 PSEG 39.4% 37.0% 38.8% 37.8% PSE&G 38.2% 38.5% 38.7% 38.6% Power 40.3% 39.4% 38.6% 38.6% For the three months ended September 30, 2015 , PSE&G's effective tax rate was lower than the statutory tax rate of 40.85% due primarily to the beneficial impact of plant related flow-through items. For the nine months ended September 30, 2015 , PSEG's and Power’s effective tax rates were lower than the statutory tax rate of 40.85% primarily due to a manufacturing deduction under Section 199 of the Internal Revenue Code (IRC) and the tax benefit associated with the income tax rate differential of carrying back federal net operating tax losses under section 172(f) of the IRC. PSE&G's effective tax rate was lower than the statutory tax rate due primarily to the beneficial impact of plant related flow-through items. For the three months and nine months ended September 30, 2015 , as compared to the same periods in the prior year, PSEG's increase was due primarily to the absence of the 2014 audit settlement. In August 2014, PSEG received notice from the Internal Revenue Service (IRS) that the audit settlement covering tax years 2007 through 2010 had been approved by the Joint Committee on Taxation. This effectively settled all issues with the IRS through 2010. In September 2014, PSEG received refunds from the IRS totaling $121 million , representing the net settlement of all disputed amounts, including interest, through the tax year 2010. As a result of the settlement of this audit, PSEG recorded a $12 million reduction of tax expense in the quarter ended September 30, 2014 . |
PSE And G [Member] | |
Income Taxes [Line Items] | |
Income Taxes | Income Taxes PSEG’s, PSE&G’s and Power's effective tax rates for the three months and nine months ended September 30, 2015 and 2014 were as follows: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 PSEG 39.4% 37.0% 38.8% 37.8% PSE&G 38.2% 38.5% 38.7% 38.6% Power 40.3% 39.4% 38.6% 38.6% For the three months ended September 30, 2015 , PSE&G's effective tax rate was lower than the statutory tax rate of 40.85% due primarily to the beneficial impact of plant related flow-through items. For the nine months ended September 30, 2015 , PSEG's and Power’s effective tax rates were lower than the statutory tax rate of 40.85% primarily due to a manufacturing deduction under Section 199 of the Internal Revenue Code (IRC) and the tax benefit associated with the income tax rate differential of carrying back federal net operating tax losses under section 172(f) of the IRC. PSE&G's effective tax rate was lower than the statutory tax rate due primarily to the beneficial impact of plant related flow-through items. For the three months and nine months ended September 30, 2015 , as compared to the same periods in the prior year, PSEG's increase was due primarily to the absence of the 2014 audit settlement. In August 2014, PSEG received notice from the Internal Revenue Service (IRS) that the audit settlement covering tax years 2007 through 2010 had been approved by the Joint Committee on Taxation. This effectively settled all issues with the IRS through 2010. In September 2014, PSEG received refunds from the IRS totaling $121 million , representing the net settlement of all disputed amounts, including interest, through the tax year 2010. As a result of the settlement of this audit, PSEG recorded a $12 million reduction of tax expense in the quarter ended September 30, 2014 . |
Power [Member] | |
Income Taxes [Line Items] | |
Income Taxes | Income Taxes PSEG’s, PSE&G’s and Power's effective tax rates for the three months and nine months ended September 30, 2015 and 2014 were as follows: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 PSEG 39.4% 37.0% 38.8% 37.8% PSE&G 38.2% 38.5% 38.7% 38.6% Power 40.3% 39.4% 38.6% 38.6% For the three months ended September 30, 2015 , PSE&G's effective tax rate was lower than the statutory tax rate of 40.85% due primarily to the beneficial impact of plant related flow-through items. For the nine months ended September 30, 2015 , PSEG's and Power’s effective tax rates were lower than the statutory tax rate of 40.85% primarily due to a manufacturing deduction under Section 199 of the Internal Revenue Code (IRC) and the tax benefit associated with the income tax rate differential of carrying back federal net operating tax losses under section 172(f) of the IRC. PSE&G's effective tax rate was lower than the statutory tax rate due primarily to the beneficial impact of plant related flow-through items. For the three months and nine months ended September 30, 2015 , as compared to the same periods in the prior year, PSEG's increase was due primarily to the absence of the 2014 audit settlement. In August 2014, PSEG received notice from the Internal Revenue Service (IRS) that the audit settlement covering tax years 2007 through 2010 had been approved by the Joint Committee on Taxation. This effectively settled all issues with the IRS through 2010. In September 2014, PSEG received refunds from the IRS totaling $121 million , representing the net settlement of all disputed amounts, including interest, through the tax year 2010. As a result of the settlement of this audit, PSEG recorded a $12 million reduction of tax expense in the quarter ended September 30, 2014 . |
Accumulated Other Comprehensive
Accumulated Other Comprehensive Income (Loss), Net of Tax | 9 Months Ended |
Sep. 30, 2015 | |
Accumulated Other Comprehensive Income (Loss) [Line Items] | |
Accumulated Other Comprehensive Income (Loss), Net of Tax | Accumulated Other Comprehensive Income (Loss), Net of Tax PSEG Other Comprehensive Income (Loss) Three Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2015 $ 1 $ (395 ) $ 117 $ (277 ) Other Comprehensive Income before Reclassifications — — (46 ) (46 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) — 9 15 24 Net Current Period Other Comprehensive Income (Loss) — 9 (31 ) (22 ) Balance as of September 30, 2015 $ 1 $ (386 ) $ 86 $ (299 ) Other Comprehensive Income (Loss) Three Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2014 $ 1 $ (232 ) $ 158 $ (73 ) Other Comprehensive Income before Reclassifications 2 — (15 ) (13 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (1 ) 3 (15 ) (13 ) Net Current Period Other Comprehensive Income (Loss) 1 3 (30 ) (26 ) Balance as of September 30, 2014 $ 2 $ (229 ) $ 128 $ (99 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2014 $ 10 $ (411 ) $ 118 $ (283 ) Other Comprehensive Income before Reclassifications 1 — (44 ) (43 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (10 ) 25 12 27 Net Current Period Other Comprehensive Income (Loss) (9 ) 25 (32 ) (16 ) Balance as of September 30, 2015 $ 1 $ (386 ) $ 86 $ (299 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2013 $ (2 ) $ (238 ) $ 145 $ (95 ) Other Comprehensive Income before Reclassifications (2 ) — 19 17 Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) 6 9 (36 ) (21 ) Net Current Period Other Comprehensive Income (Loss) 4 9 (17 ) (4 ) Balance as of September 30, 2014 $ 2 $ (229 ) $ 128 $ (99 ) Power Other Comprehensive Income (Loss) Three Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2015 $ 2 $ (337 ) $ 112 $ (223 ) Other Comprehensive Income before Reclassifications — — (43 ) (43 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) — 7 14 21 Net Current Period Other Comprehensive Income (Loss) — 7 (29 ) (22 ) Balance as of September 30, 2015 $ 2 $ (330 ) $ 83 $ (245 ) Other Comprehensive Income (Loss) Three Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2014 $ 2 $ (199 ) $ 153 $ (44 ) Other Comprehensive Income before Reclassifications 2 — (14 ) (12 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (1 ) 2 (16 ) (15 ) Net Current Period Other Comprehensive Income (Loss) 1 2 (30 ) (27 ) Balance as of September 30, 2014 $ 3 $ (197 ) $ 123 $ (71 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2014 $ 11 $ (351 ) $ 112 $ (228 ) Other Comprehensive Income before Reclassifications 1 — (41 ) (40 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (10 ) 21 12 23 Net Current Period Other Comprehensive Income (Loss) (9 ) 21 (29 ) (17 ) Balance as of September 30, 2015 $ 2 $ (330 ) $ 83 $ (245 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2013 $ (1 ) $ (204 ) $ 142 $ (63 ) Other Comprehensive Income before Reclassifications (2 ) — 17 15 Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) 6 7 (36 ) (23 ) Net Current Period Other Comprehensive Income (Loss) 4 7 (19 ) (8 ) Balance as of September 30, 2014 $ 3 $ (197 ) $ 123 $ (71 ) PSEG Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2015 September 30, 2015 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ — $ — $ — $ 17 $ (7 ) $ 10 Total Cash Flow Hedges — — — 17 (7 ) 10 Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 9 (3 ) 6 Amortization of Actuarial Loss O&M Expense (17 ) 6 (11 ) (51 ) 20 (31 ) Total Pension and OPEB Plans (14 ) 5 (9 ) (42 ) 17 (25 ) Available-for-Sale Securities Realized Gains Other Income 14 (7 ) 7 49 (25 ) 24 Realized Losses Other Deductions (12 ) 5 (7 ) (25 ) 12 (13 ) Other-Than-Temporary Impairments (OTTI) OTTI (30 ) 15 (15 ) (45 ) 22 (23 ) Total Available-for-Sale Securities (28 ) 13 (15 ) (21 ) 9 (12 ) Total $ (42 ) $ 18 $ (24 ) $ (46 ) $ 19 $ (27 ) PSEG Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2014 September 30, 2014 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ 1 $ — $ 1 $ (11 ) $ 5 $ (6 ) Total Cash Flow Hedges 1 — 1 (11 ) 5 (6 ) Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 8 (3 ) 5 Amortization of Actuarial Loss O&M Expense (8 ) 3 (5 ) (22 ) 8 (14 ) Total Pension and OPEB Plans (5 ) 2 (3 ) (14 ) 5 (9 ) Available-for-Sale Securities Realized Gains Other Income 47 (24 ) 23 105 (54 ) 51 Realized Losses Other Deductions (5 ) 2 (3 ) (15 ) 7 (8 ) OTTI OTTI (10 ) 5 (5 ) (14 ) 7 (7 ) Total Available-for-Sale Securities 32 (17 ) 15 76 (40 ) 36 Total $ 28 $ (15 ) $ 13 $ 51 $ (30 ) $ 21 Power Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2015 September 30, 2015 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ — $ — $ — $ 17 $ (7 ) $ 10 Total Cash Flow Hedges — — — 17 (7 ) 10 Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 9 (3 ) 6 Amortization of Actuarial Loss O&M Expense (15 ) 6 (9 ) (45 ) 18 (27 ) Total Pension and OPEB Plans (12 ) 5 (7 ) (36 ) 15 (21 ) Available-for-Sale Securities Realized Gains Other Income 14 (7 ) 7 47 (24 ) 23 Realized Losses Other Deductions (11 ) 5 (6 ) (24 ) 12 (12 ) OTTI OTTI (30 ) 15 (15 ) (45 ) 22 (23 ) Total Available-for-Sale Securities (27 ) 13 (14 ) (22 ) 10 (12 ) Total $ (39 ) $ 18 $ (21 ) $ (41 ) $ 18 $ (23 ) Power Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2014 September 30, 2014 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ 1 $ — $ 1 $ (11 ) $ 5 $ (6 ) Total Cash Flow Hedges 1 — 1 (11 ) 5 (6 ) Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 7 (3 ) 4 Amortization of Actuarial Loss O&M Expense (6 ) 2 (4 ) (18 ) 7 (11 ) Total Pension and OPEB Plans (3 ) 1 (2 ) (11 ) 4 (7 ) Available-for-Sale Securities Realized Gains Other Income 45 (23 ) 22 101 (52 ) 49 Realized Losses Other Deductions (2 ) 1 (1 ) (12 ) 6 (6 ) OTTI OTTI (10 ) 5 (5 ) (14 ) 7 (7 ) Total Available-for-Sale Securities 33 (17 ) 16 75 (39 ) 36 Total $ 31 $ (16 ) $ 15 $ 53 $ (30 ) $ 23 |
Power [Member] | |
Accumulated Other Comprehensive Income (Loss) [Line Items] | |
Accumulated Other Comprehensive Income (Loss), Net of Tax | Accumulated Other Comprehensive Income (Loss), Net of Tax PSEG Other Comprehensive Income (Loss) Three Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2015 $ 1 $ (395 ) $ 117 $ (277 ) Other Comprehensive Income before Reclassifications — — (46 ) (46 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) — 9 15 24 Net Current Period Other Comprehensive Income (Loss) — 9 (31 ) (22 ) Balance as of September 30, 2015 $ 1 $ (386 ) $ 86 $ (299 ) Other Comprehensive Income (Loss) Three Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2014 $ 1 $ (232 ) $ 158 $ (73 ) Other Comprehensive Income before Reclassifications 2 — (15 ) (13 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (1 ) 3 (15 ) (13 ) Net Current Period Other Comprehensive Income (Loss) 1 3 (30 ) (26 ) Balance as of September 30, 2014 $ 2 $ (229 ) $ 128 $ (99 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2014 $ 10 $ (411 ) $ 118 $ (283 ) Other Comprehensive Income before Reclassifications 1 — (44 ) (43 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (10 ) 25 12 27 Net Current Period Other Comprehensive Income (Loss) (9 ) 25 (32 ) (16 ) Balance as of September 30, 2015 $ 1 $ (386 ) $ 86 $ (299 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2013 $ (2 ) $ (238 ) $ 145 $ (95 ) Other Comprehensive Income before Reclassifications (2 ) — 19 17 Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) 6 9 (36 ) (21 ) Net Current Period Other Comprehensive Income (Loss) 4 9 (17 ) (4 ) Balance as of September 30, 2014 $ 2 $ (229 ) $ 128 $ (99 ) Power Other Comprehensive Income (Loss) Three Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2015 $ 2 $ (337 ) $ 112 $ (223 ) Other Comprehensive Income before Reclassifications — — (43 ) (43 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) — 7 14 21 Net Current Period Other Comprehensive Income (Loss) — 7 (29 ) (22 ) Balance as of September 30, 2015 $ 2 $ (330 ) $ 83 $ (245 ) Other Comprehensive Income (Loss) Three Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2014 $ 2 $ (199 ) $ 153 $ (44 ) Other Comprehensive Income before Reclassifications 2 — (14 ) (12 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (1 ) 2 (16 ) (15 ) Net Current Period Other Comprehensive Income (Loss) 1 2 (30 ) (27 ) Balance as of September 30, 2014 $ 3 $ (197 ) $ 123 $ (71 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2014 $ 11 $ (351 ) $ 112 $ (228 ) Other Comprehensive Income before Reclassifications 1 — (41 ) (40 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (10 ) 21 12 23 Net Current Period Other Comprehensive Income (Loss) (9 ) 21 (29 ) (17 ) Balance as of September 30, 2015 $ 2 $ (330 ) $ 83 $ (245 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2013 $ (1 ) $ (204 ) $ 142 $ (63 ) Other Comprehensive Income before Reclassifications (2 ) — 17 15 Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) 6 7 (36 ) (23 ) Net Current Period Other Comprehensive Income (Loss) 4 7 (19 ) (8 ) Balance as of September 30, 2014 $ 3 $ (197 ) $ 123 $ (71 ) PSEG Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2015 September 30, 2015 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ — $ — $ — $ 17 $ (7 ) $ 10 Total Cash Flow Hedges — — — 17 (7 ) 10 Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 9 (3 ) 6 Amortization of Actuarial Loss O&M Expense (17 ) 6 (11 ) (51 ) 20 (31 ) Total Pension and OPEB Plans (14 ) 5 (9 ) (42 ) 17 (25 ) Available-for-Sale Securities Realized Gains Other Income 14 (7 ) 7 49 (25 ) 24 Realized Losses Other Deductions (12 ) 5 (7 ) (25 ) 12 (13 ) Other-Than-Temporary Impairments (OTTI) OTTI (30 ) 15 (15 ) (45 ) 22 (23 ) Total Available-for-Sale Securities (28 ) 13 (15 ) (21 ) 9 (12 ) Total $ (42 ) $ 18 $ (24 ) $ (46 ) $ 19 $ (27 ) PSEG Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2014 September 30, 2014 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ 1 $ — $ 1 $ (11 ) $ 5 $ (6 ) Total Cash Flow Hedges 1 — 1 (11 ) 5 (6 ) Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 8 (3 ) 5 Amortization of Actuarial Loss O&M Expense (8 ) 3 (5 ) (22 ) 8 (14 ) Total Pension and OPEB Plans (5 ) 2 (3 ) (14 ) 5 (9 ) Available-for-Sale Securities Realized Gains Other Income 47 (24 ) 23 105 (54 ) 51 Realized Losses Other Deductions (5 ) 2 (3 ) (15 ) 7 (8 ) OTTI OTTI (10 ) 5 (5 ) (14 ) 7 (7 ) Total Available-for-Sale Securities 32 (17 ) 15 76 (40 ) 36 Total $ 28 $ (15 ) $ 13 $ 51 $ (30 ) $ 21 Power Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2015 September 30, 2015 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ — $ — $ — $ 17 $ (7 ) $ 10 Total Cash Flow Hedges — — — 17 (7 ) 10 Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 9 (3 ) 6 Amortization of Actuarial Loss O&M Expense (15 ) 6 (9 ) (45 ) 18 (27 ) Total Pension and OPEB Plans (12 ) 5 (7 ) (36 ) 15 (21 ) Available-for-Sale Securities Realized Gains Other Income 14 (7 ) 7 47 (24 ) 23 Realized Losses Other Deductions (11 ) 5 (6 ) (24 ) 12 (12 ) OTTI OTTI (30 ) 15 (15 ) (45 ) 22 (23 ) Total Available-for-Sale Securities (27 ) 13 (14 ) (22 ) 10 (12 ) Total $ (39 ) $ 18 $ (21 ) $ (41 ) $ 18 $ (23 ) Power Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2014 September 30, 2014 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ 1 $ — $ 1 $ (11 ) $ 5 $ (6 ) Total Cash Flow Hedges 1 — 1 (11 ) 5 (6 ) Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 7 (3 ) 4 Amortization of Actuarial Loss O&M Expense (6 ) 2 (4 ) (18 ) 7 (11 ) Total Pension and OPEB Plans (3 ) 1 (2 ) (11 ) 4 (7 ) Available-for-Sale Securities Realized Gains Other Income 45 (23 ) 22 101 (52 ) 49 Realized Losses Other Deductions (2 ) 1 (1 ) (12 ) 6 (6 ) OTTI OTTI (10 ) 5 (5 ) (14 ) 7 (7 ) Total Available-for-Sale Securities 33 (17 ) 16 75 (39 ) 36 Total $ 31 $ (16 ) $ 15 $ 53 $ (30 ) $ 23 |
Earnings Per Share (EPS) and Di
Earnings Per Share (EPS) and Dividends | 9 Months Ended |
Sep. 30, 2015 | |
Earnings Per Share [Abstract] | |
Earnings Per Share (EPS) and Dividends | Earnings Per Share (EPS) and Dividends Diluted EPS is calculated by dividing Net Income by the weighted average number of shares of common stock outstanding, including shares issuable upon exercise of stock options outstanding or vesting of restricted stock awards granted under our stock compensation plans and upon payment of performance units or restricted stock units. The following table shows the effect of these stock options, performance units and restricted stock units on the weighted average number of shares outstanding used in calculating diluted EPS. Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Basic Diluted Basic Diluted Basic Diluted Basic Diluted EPS Numerator (Millions) Net Income $ 439 $ 439 $ 444 $ 444 $ 1,370 $ 1,370 $ 1,042 $ 1,042 EPS Denominator (Millions) Weighted Average Common Shares Outstanding 505 505 506 506 505 505 506 506 Effect of Stock Based Compensation Awards — 3 — 1 — 3 — 1 Total Shares 505 508 506 507 505 508 506 507 EPS Net Income $ 0.87 $ 0.87 $ 0.88 $ 0.87 $ 2.71 $ 2.70 $ 2.06 $ 2.05 Three Months Ended Nine Months Ended September 30, September 30, Dividend Payments on Common Stock 2015 2014 2015 2014 Per Share $ 0.39 $ 0.37 $ 1.17 $ 1.11 In Millions $ 198 $ 187 $ 592 $ 561 |
Financial Information By Busine
Financial Information By Business Segments | 9 Months Ended |
Sep. 30, 2015 | |
Segment Reporting Information [Line Items] | |
Financial Information By Business Segments | Financial Information by Business Segments PSE&G Power Other (A) Eliminations (B) Consolidated Millions Three Months Ended September 30, 2015 Total Operating Revenues $ 1,766 $ 1,096 $ 120 $ (294 ) $ 2,688 Net Income (Loss) 222 206 11 — 439 Gross Additions to Long-Lived Assets 716 310 13 — 1,039 Nine Months Ended September 30, 2015 Total Operating Revenues $ 5,234 $ 3,846 $ 326 $ (1,269 ) $ 8,137 Net Income (Loss) 631 707 32 — 1,370 Gross Additions to Long-Lived Assets 1,946 797 39 — 2,782 Three Months Ended September 30, 2014 Total Operating Revenues $ 1,655 $ 1,138 $ 123 $ (275 ) $ 2,641 Net Income (Loss) 200 222 22 — 444 Gross Additions to Long-Lived Assets 497 188 8 — 693 Nine Months Ended September 30, 2014 Total Operating Revenues $ 5,235 $ 3,824 $ 359 $ (1,305 ) $ 8,113 Net Income (Loss) 565 440 37 — 1,042 Gross Additions to Long-Lived Assets 1,493 414 15 — 1,922 As of September 30, 2015 Total Assets $ 22,909 $ 12,314 $ 2,775 $ (1,574 ) $ 36,424 Investments in Equity Method Subsidiaries $ — $ 116 $ 1 $ — $ 117 As of December 31, 2014 Total Assets $ 22,223 $ 12,046 $ 2,799 $ (1,735 ) $ 35,333 Investments in Equity Method Subsidiaries $ — $ 121 $ 2 $ — $ 123 (A) Includes amounts applicable to Energy Holdings and PSEG LI, which are below the quantitative threshold for separate disclosure as reportable segments. Other also includes amounts applicable to PSEG (parent corporation) and Services. (B) Intercompany eliminations, primarily related to intercompany transactions between PSE&G and Power. No gains or losses are recorded on any intercompany transactions; rather, all intercompany transactions are at cost or, in the case of the BGS and BGSS contracts between PSE&G and Power, at rates prescribed by the BPU. For a further discussion of the intercompany transactions between PSE&G and Power, see Note 17. Related-Party Transactions . |
PSE And G [Member] | |
Segment Reporting Information [Line Items] | |
Financial Information By Business Segments | Financial Information by Business Segments PSE&G Power Other (A) Eliminations (B) Consolidated Millions Three Months Ended September 30, 2015 Total Operating Revenues $ 1,766 $ 1,096 $ 120 $ (294 ) $ 2,688 Net Income (Loss) 222 206 11 — 439 Gross Additions to Long-Lived Assets 716 310 13 — 1,039 Nine Months Ended September 30, 2015 Total Operating Revenues $ 5,234 $ 3,846 $ 326 $ (1,269 ) $ 8,137 Net Income (Loss) 631 707 32 — 1,370 Gross Additions to Long-Lived Assets 1,946 797 39 — 2,782 Three Months Ended September 30, 2014 Total Operating Revenues $ 1,655 $ 1,138 $ 123 $ (275 ) $ 2,641 Net Income (Loss) 200 222 22 — 444 Gross Additions to Long-Lived Assets 497 188 8 — 693 Nine Months Ended September 30, 2014 Total Operating Revenues $ 5,235 $ 3,824 $ 359 $ (1,305 ) $ 8,113 Net Income (Loss) 565 440 37 — 1,042 Gross Additions to Long-Lived Assets 1,493 414 15 — 1,922 As of September 30, 2015 Total Assets $ 22,909 $ 12,314 $ 2,775 $ (1,574 ) $ 36,424 Investments in Equity Method Subsidiaries $ — $ 116 $ 1 $ — $ 117 As of December 31, 2014 Total Assets $ 22,223 $ 12,046 $ 2,799 $ (1,735 ) $ 35,333 Investments in Equity Method Subsidiaries $ — $ 121 $ 2 $ — $ 123 (A) Includes amounts applicable to Energy Holdings and PSEG LI, which are below the quantitative threshold for separate disclosure as reportable segments. Other also includes amounts applicable to PSEG (parent corporation) and Services. (B) Intercompany eliminations, primarily related to intercompany transactions between PSE&G and Power. No gains or losses are recorded on any intercompany transactions; rather, all intercompany transactions are at cost or, in the case of the BGS and BGSS contracts between PSE&G and Power, at rates prescribed by the BPU. For a further discussion of the intercompany transactions between PSE&G and Power, see Note 17. Related-Party Transactions . |
Power [Member] | |
Segment Reporting Information [Line Items] | |
Financial Information By Business Segments | Financial Information by Business Segments PSE&G Power Other (A) Eliminations (B) Consolidated Millions Three Months Ended September 30, 2015 Total Operating Revenues $ 1,766 $ 1,096 $ 120 $ (294 ) $ 2,688 Net Income (Loss) 222 206 11 — 439 Gross Additions to Long-Lived Assets 716 310 13 — 1,039 Nine Months Ended September 30, 2015 Total Operating Revenues $ 5,234 $ 3,846 $ 326 $ (1,269 ) $ 8,137 Net Income (Loss) 631 707 32 — 1,370 Gross Additions to Long-Lived Assets 1,946 797 39 — 2,782 Three Months Ended September 30, 2014 Total Operating Revenues $ 1,655 $ 1,138 $ 123 $ (275 ) $ 2,641 Net Income (Loss) 200 222 22 — 444 Gross Additions to Long-Lived Assets 497 188 8 — 693 Nine Months Ended September 30, 2014 Total Operating Revenues $ 5,235 $ 3,824 $ 359 $ (1,305 ) $ 8,113 Net Income (Loss) 565 440 37 — 1,042 Gross Additions to Long-Lived Assets 1,493 414 15 — 1,922 As of September 30, 2015 Total Assets $ 22,909 $ 12,314 $ 2,775 $ (1,574 ) $ 36,424 Investments in Equity Method Subsidiaries $ — $ 116 $ 1 $ — $ 117 As of December 31, 2014 Total Assets $ 22,223 $ 12,046 $ 2,799 $ (1,735 ) $ 35,333 Investments in Equity Method Subsidiaries $ — $ 121 $ 2 $ — $ 123 (A) Includes amounts applicable to Energy Holdings and PSEG LI, which are below the quantitative threshold for separate disclosure as reportable segments. Other also includes amounts applicable to PSEG (parent corporation) and Services. (B) Intercompany eliminations, primarily related to intercompany transactions between PSE&G and Power. No gains or losses are recorded on any intercompany transactions; rather, all intercompany transactions are at cost or, in the case of the BGS and BGSS contracts between PSE&G and Power, at rates prescribed by the BPU. For a further discussion of the intercompany transactions between PSE&G and Power, see Note 17. Related-Party Transactions . |
Related-Party Transactions
Related-Party Transactions | 9 Months Ended |
Sep. 30, 2015 | |
Related Party Transaction [Line Items] | |
Related-Party Transactions | Related-Party Transactions The following discussion relates to intercompany transactions, which are eliminated during the PSEG consolidation process in accordance with GAAP. PSE&G The financial statements for PSE&G include transactions with related parties presented as follows: Three Months Ended Nine Months Ended September 30, September 30, Related-Party Transactions 2015 2014 2015 2014 Millions Billings from Affiliates: Billings from Power primarily through BGS and BGSS (A) $ 294 $ 280 $ 1,287 $ 1,308 Administrative Billings from Services (B) 66 59 197 183 Total Billings from Affiliates $ 360 $ 339 $ 1,484 $ 1,491 As of As of Related-Party Transactions September 30, 2015 December 31, 2014 Millions Receivable from PSEG (C) $ 7 $ 274 Payable to Power (A) $ 158 $ 313 Payable to Services (B) 50 66 Accounts Payable—Affiliated Companies $ 208 $ 379 Working Capital Advances to Services (D) $ 33 $ 33 Long-Term Accrued Taxes Payable $ 165 $ 116 Power The financial statements for Power include transactions with related parties presented as follows: Three Months Ended Nine Months Ended September 30, September 30, Related-Party Transactions 2015 2014 2015 2014 Millions Billings to Affiliates: Billings to PSE&G primarily through BGS and BGSS (A) $ 294 $ 280 $ 1,287 $ 1,308 Billings from Affiliates: Administrative Billings from Services (B) $ 44 $ 41 $ 135 $ 129 As of As of Related-Party Transactions September 30, 2015 December 31, 2014 Millions Receivables from PSE&G (A) $ 158 $ 313 Payable to Services (B) $ 26 $ 23 Payable to PSEG (C) 91 95 Accounts Payable—Affiliated Companies $ 117 $ 118 Short-Term Loan Due (to) from Affiliate (E) $ 865 $ 584 Working Capital Advances to Services (D) $ 17 $ 17 Long-Term Accrued Taxes Payable $ 54 $ 41 (A) PSE&G has entered into a requirements contract with Power under which Power provides the gas supply services needed to meet PSE&G’s BGSS and other contractual requirements. Power has also entered into contracts to supply energy, capacity and ancillary services to PSE&G through the BGS auction process. (B) Services provides and bills administrative services to PSE&G and Power at cost. In addition, PSE&G and Power have other payables to Services, including amounts related to certain common costs, such as pension and OPEB costs, which Services pays on behalf of each of the operating companies. (C) PSEG files a consolidated federal income tax return with its affiliated companies. A tax allocation agreement exists between PSEG and each of its affiliated companies. The general operation of these agreements is that the subsidiary company will compute its taxable income on a stand-alone basis. If the result is a net tax liability, such amount shall be paid to PSEG. If there are net operating losses and/or tax credits, the subsidiary shall receive payment for the tax savings from PSEG to the extent that PSEG is able to utilize those benefits. (D) PSE&G and Power have advanced working capital to Services. The amounts are included in Other Noncurrent Assets on PSE&G’s and Power’s Condensed Consolidated Balance Sheets. (E) Power’s short-term loans with PSEG are for working capital and other short-term needs. Interest Income and Interest Expense relating to these short-term funding activities were immaterial. |
PSE And G [Member] | |
Related Party Transaction [Line Items] | |
Related-Party Transactions | Related-Party Transactions The following discussion relates to intercompany transactions, which are eliminated during the PSEG consolidation process in accordance with GAAP. PSE&G The financial statements for PSE&G include transactions with related parties presented as follows: Three Months Ended Nine Months Ended September 30, September 30, Related-Party Transactions 2015 2014 2015 2014 Millions Billings from Affiliates: Billings from Power primarily through BGS and BGSS (A) $ 294 $ 280 $ 1,287 $ 1,308 Administrative Billings from Services (B) 66 59 197 183 Total Billings from Affiliates $ 360 $ 339 $ 1,484 $ 1,491 As of As of Related-Party Transactions September 30, 2015 December 31, 2014 Millions Receivable from PSEG (C) $ 7 $ 274 Payable to Power (A) $ 158 $ 313 Payable to Services (B) 50 66 Accounts Payable—Affiliated Companies $ 208 $ 379 Working Capital Advances to Services (D) $ 33 $ 33 Long-Term Accrued Taxes Payable $ 165 $ 116 Power The financial statements for Power include transactions with related parties presented as follows: Three Months Ended Nine Months Ended September 30, September 30, Related-Party Transactions 2015 2014 2015 2014 Millions Billings to Affiliates: Billings to PSE&G primarily through BGS and BGSS (A) $ 294 $ 280 $ 1,287 $ 1,308 Billings from Affiliates: Administrative Billings from Services (B) $ 44 $ 41 $ 135 $ 129 As of As of Related-Party Transactions September 30, 2015 December 31, 2014 Millions Receivables from PSE&G (A) $ 158 $ 313 Payable to Services (B) $ 26 $ 23 Payable to PSEG (C) 91 95 Accounts Payable—Affiliated Companies $ 117 $ 118 Short-Term Loan Due (to) from Affiliate (E) $ 865 $ 584 Working Capital Advances to Services (D) $ 17 $ 17 Long-Term Accrued Taxes Payable $ 54 $ 41 (A) PSE&G has entered into a requirements contract with Power under which Power provides the gas supply services needed to meet PSE&G’s BGSS and other contractual requirements. Power has also entered into contracts to supply energy, capacity and ancillary services to PSE&G through the BGS auction process. (B) Services provides and bills administrative services to PSE&G and Power at cost. In addition, PSE&G and Power have other payables to Services, including amounts related to certain common costs, such as pension and OPEB costs, which Services pays on behalf of each of the operating companies. (C) PSEG files a consolidated federal income tax return with its affiliated companies. A tax allocation agreement exists between PSEG and each of its affiliated companies. The general operation of these agreements is that the subsidiary company will compute its taxable income on a stand-alone basis. If the result is a net tax liability, such amount shall be paid to PSEG. If there are net operating losses and/or tax credits, the subsidiary shall receive payment for the tax savings from PSEG to the extent that PSEG is able to utilize those benefits. (D) PSE&G and Power have advanced working capital to Services. The amounts are included in Other Noncurrent Assets on PSE&G’s and Power’s Condensed Consolidated Balance Sheets. (E) Power’s short-term loans with PSEG are for working capital and other short-term needs. Interest Income and Interest Expense relating to these short-term funding activities were immaterial. |
Power [Member] | |
Related Party Transaction [Line Items] | |
Related-Party Transactions | Related-Party Transactions The following discussion relates to intercompany transactions, which are eliminated during the PSEG consolidation process in accordance with GAAP. PSE&G The financial statements for PSE&G include transactions with related parties presented as follows: Three Months Ended Nine Months Ended September 30, September 30, Related-Party Transactions 2015 2014 2015 2014 Millions Billings from Affiliates: Billings from Power primarily through BGS and BGSS (A) $ 294 $ 280 $ 1,287 $ 1,308 Administrative Billings from Services (B) 66 59 197 183 Total Billings from Affiliates $ 360 $ 339 $ 1,484 $ 1,491 As of As of Related-Party Transactions September 30, 2015 December 31, 2014 Millions Receivable from PSEG (C) $ 7 $ 274 Payable to Power (A) $ 158 $ 313 Payable to Services (B) 50 66 Accounts Payable—Affiliated Companies $ 208 $ 379 Working Capital Advances to Services (D) $ 33 $ 33 Long-Term Accrued Taxes Payable $ 165 $ 116 Power The financial statements for Power include transactions with related parties presented as follows: Three Months Ended Nine Months Ended September 30, September 30, Related-Party Transactions 2015 2014 2015 2014 Millions Billings to Affiliates: Billings to PSE&G primarily through BGS and BGSS (A) $ 294 $ 280 $ 1,287 $ 1,308 Billings from Affiliates: Administrative Billings from Services (B) $ 44 $ 41 $ 135 $ 129 As of As of Related-Party Transactions September 30, 2015 December 31, 2014 Millions Receivables from PSE&G (A) $ 158 $ 313 Payable to Services (B) $ 26 $ 23 Payable to PSEG (C) 91 95 Accounts Payable—Affiliated Companies $ 117 $ 118 Short-Term Loan Due (to) from Affiliate (E) $ 865 $ 584 Working Capital Advances to Services (D) $ 17 $ 17 Long-Term Accrued Taxes Payable $ 54 $ 41 (A) PSE&G has entered into a requirements contract with Power under which Power provides the gas supply services needed to meet PSE&G’s BGSS and other contractual requirements. Power has also entered into contracts to supply energy, capacity and ancillary services to PSE&G through the BGS auction process. (B) Services provides and bills administrative services to PSE&G and Power at cost. In addition, PSE&G and Power have other payables to Services, including amounts related to certain common costs, such as pension and OPEB costs, which Services pays on behalf of each of the operating companies. (C) PSEG files a consolidated federal income tax return with its affiliated companies. A tax allocation agreement exists between PSEG and each of its affiliated companies. The general operation of these agreements is that the subsidiary company will compute its taxable income on a stand-alone basis. If the result is a net tax liability, such amount shall be paid to PSEG. If there are net operating losses and/or tax credits, the subsidiary shall receive payment for the tax savings from PSEG to the extent that PSEG is able to utilize those benefits. (D) PSE&G and Power have advanced working capital to Services. The amounts are included in Other Noncurrent Assets on PSE&G’s and Power’s Condensed Consolidated Balance Sheets. (E) Power’s short-term loans with PSEG are for working capital and other short-term needs. Interest Income and Interest Expense relating to these short-term funding activities were immaterial. |
Guarantees of Debt
Guarantees of Debt | 9 Months Ended |
Sep. 30, 2015 | |
Debt Instrument [Line Items] | |
Guarantees of Debt | Guarantees of Debt Each series of Power’s Senior Notes, Pollution Control Notes and its syndicated revolving credit facilities are fully and unconditionally and jointly and severally guaranteed by its subsidiaries, PSEG Fossil LLC, PSEG Nuclear LLC and PSEG Energy Resources & Trade LLC. The following tables present condensed financial information for the guarantor subsidiaries, as well as Power’s non-guarantor subsidiaries. Power Guarantor Subsidiaries Other Subsidiaries Consolidating Adjustments Consolidated Millions Three Months Ended September 30, 2015 Operating Revenues $ — $ 1,084 $ 37 $ (25 ) $ 1,096 Operating Expenses 3 692 35 (25 ) 705 Operating Income (Loss) (3 ) 392 2 — 391 Equity Earnings (Losses) of Subsidiaries 220 (2 ) 3 (218 ) 3 Other Income 10 26 — (11 ) 25 Other Deductions — (14 ) — — (14 ) Other-Than-Temporary Impairments — (30 ) — — (30 ) Interest Expense (28 ) (8 ) (5 ) 11 (30 ) Income Tax Benefit (Expense) 7 (148 ) 2 — (139 ) Net Income (Loss) $ 206 $ 216 $ 2 $ (218 ) $ 206 Comprehensive Income (Loss) $ 184 $ 187 $ 2 $ (189 ) $ 184 Nine Months Ended September 30, 2015 Operating Revenues $ — $ 3,811 $ 144 $ (109 ) $ 3,846 Operating Expenses 7 2,610 135 (109 ) 2,643 Operating Income (Loss) (7 ) 1,201 9 — 1,203 Equity Earnings (Losses) of Subsidiaries 755 (4 ) 11 (751 ) 11 Other Income 33 111 — (35 ) 109 Other Deductions (1 ) (31 ) — — (32 ) Other-Than-Temporary Impairments — (45 ) — — (45 ) Interest Expense (90 ) (24 ) (15 ) 35 (94 ) Income Tax Benefit (Expense) 17 (463 ) 1 — (445 ) Net Income (Loss) $ 707 $ 745 $ 6 $ (751 ) $ 707 Comprehensive Income (Loss) $ 690 $ 707 $ 6 $ (713 ) $ 690 Nine Months Ended September 30, 2015 Net Cash Provided By (Used In) Operating Activities $ 435 $ 1,826 $ 66 $ (769 ) $ 1,558 Net Cash Provided By (Used In) Investing Activities $ (656 ) $ (1,382 ) $ (303 ) $ 1,191 $ (1,150 ) Net Cash Provided By (Used In) Financing Activities $ 221 $ (446 ) $ 245 $ (422 ) $ (402 ) Power Guarantor Subsidiaries Other Subsidiaries Consolidating Adjustments Consolidated Millions Three Months Ended September 30, 2014 Operating Revenues $ — $ 1,125 $ 36 $ (23 ) $ 1,138 Operating Expenses 3 772 32 (22 ) 785 Operating Income (Loss) (3 ) 353 4 (1 ) 353 Equity Earnings (Losses) of Subsidiaries 225 (1 ) 4 (224 ) 4 Other Income 9 55 — (8 ) 56 Other Deductions (3 ) (4 ) — 1 (6 ) Other-Than-Temporary Impairments — (10 ) — — (10 ) Interest Expense (24 ) (10 ) (4 ) 7 (31 ) Income Tax Benefit (Expense) 18 (161 ) (1 ) — (144 ) Net Income (Loss) $ 222 $ 222 $ 3 $ (225 ) $ 222 Comprehensive Income (Loss) $ 195 $ 191 $ 3 $ (194 ) $ 195 Nine Months Ended September 30, 2014 Operating Revenues $ — $ 3,781 $ 118 $ (75 ) $ 3,824 Operating Expenses 12 3,079 106 (75 ) 3,122 Operating Income (Loss) (12 ) 702 12 — 702 Equity Earnings (Losses) of Subsidiaries 459 (4 ) 11 (455 ) 11 Other Income 25 135 — (25 ) 135 Other Deductions (7 ) (18 ) — — (25 ) Other-Than-Temporary Impairments — (14 ) — — (14 ) Interest Expense (79 ) (23 ) (14 ) 24 (92 ) Income Tax Benefit (Expense) 54 (329 ) (2 ) — (277 ) Net Income (Loss) $ 440 $ 449 $ 7 $ (456 ) $ 440 Comprehensive Income (Loss) $ 432 $ 433 $ 7 $ (440 ) $ 432 Nine Months Ended September 30, 2014 Net Cash Provided By (Used In) Operating Activities $ 471 $ 1,252 $ 53 $ (666 ) $ 1,110 Net Cash Provided By (Used In) Investing Activities $ 187 $ (559 ) $ (24 ) $ 70 $ (326 ) Net Cash Provided By (Used In) Financing Activities $ (652 ) $ (693 ) $ (29 ) $ 596 $ (778 ) Power Guarantor Subsidiaries Other Subsidiaries Consolidating Adjustments Consolidated Millions As of September 30, 2015 Current Assets $ 4,678 $ 1,786 $ 134 $ (4,374 ) $ 2,224 Property, Plant and Equipment, net 82 6,390 1,435 — 7,907 Investment in Subsidiaries 4,555 349 — (4,904 ) — Noncurrent Assets 264 1,962 133 (176 ) 2,183 Total Assets $ 9,579 $ 10,487 $ 1,702 $ (9,454 ) $ 12,314 Current Liabilities $ 1,581 $ 3,595 $ 772 $ (4,374 ) $ 1,574 Noncurrent Liabilities 458 2,563 355 (176 ) 3,200 Long-Term Debt 1,691 — — — 1,691 Member's Equity 5,849 4,329 575 (4,904 ) 5,849 Total Liabilities and Member's Equity $ 9,579 $ 10,487 $ 1,702 $ (9,454 ) $ 12,314 As of December 31, 2014 Current Assets $ 4,263 $ 2,037 $ 150 $ (4,091 ) $ 2,359 Property, Plant and Equipment, net 81 6,265 1,169 — 7,515 Investment in Subsidiaries 4,516 120 — (4,636 ) — Noncurrent Assets 278 1,952 137 (195 ) 2,172 Total Assets $ 9,138 $ 10,374 $ 1,456 $ (8,922 ) $ 12,046 Current Liabilities $ 883 $ 3,606 $ 786 $ (4,091 ) $ 1,184 Noncurrent Liabilities 454 2,442 360 (195 ) 3,061 Long-Term Debt 2,243 — — — 2,243 Member's Equity 5,558 4,326 310 (4,636 ) 5,558 Total Liabilities and Member's Equity $ 9,138 $ 10,374 $ 1,456 $ (8,922 ) $ 12,046 |
Power [Member] | |
Debt Instrument [Line Items] | |
Guarantees of Debt | Guarantees of Debt Each series of Power’s Senior Notes, Pollution Control Notes and its syndicated revolving credit facilities are fully and unconditionally and jointly and severally guaranteed by its subsidiaries, PSEG Fossil LLC, PSEG Nuclear LLC and PSEG Energy Resources & Trade LLC. The following tables present condensed financial information for the guarantor subsidiaries, as well as Power’s non-guarantor subsidiaries. Power Guarantor Subsidiaries Other Subsidiaries Consolidating Adjustments Consolidated Millions Three Months Ended September 30, 2015 Operating Revenues $ — $ 1,084 $ 37 $ (25 ) $ 1,096 Operating Expenses 3 692 35 (25 ) 705 Operating Income (Loss) (3 ) 392 2 — 391 Equity Earnings (Losses) of Subsidiaries 220 (2 ) 3 (218 ) 3 Other Income 10 26 — (11 ) 25 Other Deductions — (14 ) — — (14 ) Other-Than-Temporary Impairments — (30 ) — — (30 ) Interest Expense (28 ) (8 ) (5 ) 11 (30 ) Income Tax Benefit (Expense) 7 (148 ) 2 — (139 ) Net Income (Loss) $ 206 $ 216 $ 2 $ (218 ) $ 206 Comprehensive Income (Loss) $ 184 $ 187 $ 2 $ (189 ) $ 184 Nine Months Ended September 30, 2015 Operating Revenues $ — $ 3,811 $ 144 $ (109 ) $ 3,846 Operating Expenses 7 2,610 135 (109 ) 2,643 Operating Income (Loss) (7 ) 1,201 9 — 1,203 Equity Earnings (Losses) of Subsidiaries 755 (4 ) 11 (751 ) 11 Other Income 33 111 — (35 ) 109 Other Deductions (1 ) (31 ) — — (32 ) Other-Than-Temporary Impairments — (45 ) — — (45 ) Interest Expense (90 ) (24 ) (15 ) 35 (94 ) Income Tax Benefit (Expense) 17 (463 ) 1 — (445 ) Net Income (Loss) $ 707 $ 745 $ 6 $ (751 ) $ 707 Comprehensive Income (Loss) $ 690 $ 707 $ 6 $ (713 ) $ 690 Nine Months Ended September 30, 2015 Net Cash Provided By (Used In) Operating Activities $ 435 $ 1,826 $ 66 $ (769 ) $ 1,558 Net Cash Provided By (Used In) Investing Activities $ (656 ) $ (1,382 ) $ (303 ) $ 1,191 $ (1,150 ) Net Cash Provided By (Used In) Financing Activities $ 221 $ (446 ) $ 245 $ (422 ) $ (402 ) Power Guarantor Subsidiaries Other Subsidiaries Consolidating Adjustments Consolidated Millions Three Months Ended September 30, 2014 Operating Revenues $ — $ 1,125 $ 36 $ (23 ) $ 1,138 Operating Expenses 3 772 32 (22 ) 785 Operating Income (Loss) (3 ) 353 4 (1 ) 353 Equity Earnings (Losses) of Subsidiaries 225 (1 ) 4 (224 ) 4 Other Income 9 55 — (8 ) 56 Other Deductions (3 ) (4 ) — 1 (6 ) Other-Than-Temporary Impairments — (10 ) — — (10 ) Interest Expense (24 ) (10 ) (4 ) 7 (31 ) Income Tax Benefit (Expense) 18 (161 ) (1 ) — (144 ) Net Income (Loss) $ 222 $ 222 $ 3 $ (225 ) $ 222 Comprehensive Income (Loss) $ 195 $ 191 $ 3 $ (194 ) $ 195 Nine Months Ended September 30, 2014 Operating Revenues $ — $ 3,781 $ 118 $ (75 ) $ 3,824 Operating Expenses 12 3,079 106 (75 ) 3,122 Operating Income (Loss) (12 ) 702 12 — 702 Equity Earnings (Losses) of Subsidiaries 459 (4 ) 11 (455 ) 11 Other Income 25 135 — (25 ) 135 Other Deductions (7 ) (18 ) — — (25 ) Other-Than-Temporary Impairments — (14 ) — — (14 ) Interest Expense (79 ) (23 ) (14 ) 24 (92 ) Income Tax Benefit (Expense) 54 (329 ) (2 ) — (277 ) Net Income (Loss) $ 440 $ 449 $ 7 $ (456 ) $ 440 Comprehensive Income (Loss) $ 432 $ 433 $ 7 $ (440 ) $ 432 Nine Months Ended September 30, 2014 Net Cash Provided By (Used In) Operating Activities $ 471 $ 1,252 $ 53 $ (666 ) $ 1,110 Net Cash Provided By (Used In) Investing Activities $ 187 $ (559 ) $ (24 ) $ 70 $ (326 ) Net Cash Provided By (Used In) Financing Activities $ (652 ) $ (693 ) $ (29 ) $ 596 $ (778 ) Power Guarantor Subsidiaries Other Subsidiaries Consolidating Adjustments Consolidated Millions As of September 30, 2015 Current Assets $ 4,678 $ 1,786 $ 134 $ (4,374 ) $ 2,224 Property, Plant and Equipment, net 82 6,390 1,435 — 7,907 Investment in Subsidiaries 4,555 349 — (4,904 ) — Noncurrent Assets 264 1,962 133 (176 ) 2,183 Total Assets $ 9,579 $ 10,487 $ 1,702 $ (9,454 ) $ 12,314 Current Liabilities $ 1,581 $ 3,595 $ 772 $ (4,374 ) $ 1,574 Noncurrent Liabilities 458 2,563 355 (176 ) 3,200 Long-Term Debt 1,691 — — — 1,691 Member's Equity 5,849 4,329 575 (4,904 ) 5,849 Total Liabilities and Member's Equity $ 9,579 $ 10,487 $ 1,702 $ (9,454 ) $ 12,314 As of December 31, 2014 Current Assets $ 4,263 $ 2,037 $ 150 $ (4,091 ) $ 2,359 Property, Plant and Equipment, net 81 6,265 1,169 — 7,515 Investment in Subsidiaries 4,516 120 — (4,636 ) — Noncurrent Assets 278 1,952 137 (195 ) 2,172 Total Assets $ 9,138 $ 10,374 $ 1,456 $ (8,922 ) $ 12,046 Current Liabilities $ 883 $ 3,606 $ 786 $ (4,091 ) $ 1,184 Noncurrent Liabilities 454 2,442 360 (195 ) 3,061 Long-Term Debt 2,243 — — — 2,243 Member's Equity 5,558 4,326 310 (4,636 ) 5,558 Total Liabilities and Member's Equity $ 9,138 $ 10,374 $ 1,456 $ (8,922 ) $ 12,046 |
Organization and Basis of Pre26
Organization and Basis of Presentation (Policies) | 9 Months Ended |
Sep. 30, 2015 | |
Basis of Presentation | Basis of Presentation The respective financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC) applicable to Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States (GAAP) have been condensed or omitted pursuant to such rules and regulations. These Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements (Notes) should be read in conjunction with, and update and supplement matters discussed in, the Annual Report on Form 10-K for the year ended December 31, 2014 . The unaudited condensed consolidated financial information furnished herein reflects all adjustments which are, in the opinion of management, necessary to fairly state the results for the interim periods presented. All such adjustments are of a normal recurring nature. All intercompany accounts and transactions are eliminated in consolidation. The year-end Condensed Consolidated Balance Sheets were derived from the audited Consolidated Financial Statements included in the Annual Report on Form 10-K for the year ended December 31, 2014 . |
Power [Member] | |
Basis of Presentation | Basis of Presentation The respective financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC) applicable to Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States (GAAP) have been condensed or omitted pursuant to such rules and regulations. These Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements (Notes) should be read in conjunction with, and update and supplement matters discussed in, the Annual Report on Form 10-K for the year ended December 31, 2014 . The unaudited condensed consolidated financial information furnished herein reflects all adjustments which are, in the opinion of management, necessary to fairly state the results for the interim periods presented. All such adjustments are of a normal recurring nature. All intercompany accounts and transactions are eliminated in consolidation. The year-end Condensed Consolidated Balance Sheets were derived from the audited Consolidated Financial Statements included in the Annual Report on Form 10-K for the year ended December 31, 2014 . |
PSE And G [Member] | |
Basis of Presentation | Basis of Presentation The respective financial statements included herein have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission (SEC) applicable to Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States (GAAP) have been condensed or omitted pursuant to such rules and regulations. These Condensed Consolidated Financial Statements and Notes to Condensed Consolidated Financial Statements (Notes) should be read in conjunction with, and update and supplement matters discussed in, the Annual Report on Form 10-K for the year ended December 31, 2014 . The unaudited condensed consolidated financial information furnished herein reflects all adjustments which are, in the opinion of management, necessary to fairly state the results for the interim periods presented. All such adjustments are of a normal recurring nature. All intercompany accounts and transactions are eliminated in consolidation. The year-end Condensed Consolidated Balance Sheets were derived from the audited Consolidated Financial Statements included in the Annual Report on Form 10-K for the year ended December 31, 2014 . |
Recent Accounting Standards (Po
Recent Accounting Standards (Policies) | 9 Months Ended |
Sep. 30, 2015 | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
New Standards Issued But Not Yet Adopted | New Standards Issued But Not Yet Adopted Revenue from Contracts with Customers This accounting standard was issued to clarify the principles for recognizing revenue and to develop a common standard that would remove inconsistencies in revenue requirements; improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets; and provide improved disclosures. The guidance provides a five-step model to be used for recognizing revenue for the transfer of promised goods and services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The update was originally to be effective for annual and interim reporting periods beginning after December 15, 2016; however, the Financial Accounting Standards Board issued new guidance deferring the effective date by one year to periods beginning after December 31, 2017. Early application will be permitted as of the original effective date. We are currently analyzing the impact of this standard on our financial statements. Amendments to the Consolidation Analysis This standard was issued to respond to concerns regarding the current accounting for consolidation of certain legal entities. Under the new standard, all legal entities are subject to reevaluation under a revised consolidation model which will determine whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities; eliminate the presumption that a general partner should consolidate a limited partnership; affect the consolidation analysis of reporting entities that are involved with VIEs and provide a scope exception from consolidation guidance for reporting entities with interests in certain legal entities who must comply with other requirements. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We are currently analyzing the impact of this standard on our financial statements. Simplifying the Presentation of Debt Issuance Costs This standard was issued to simplify presentation of debt issuance costs. The standard will require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by this standard. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We do not expect the impact of adoption of this standard to be material to our Condensed Consolidated Balance Sheets. |
PSE And G [Member] | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
New Standards Issued But Not Yet Adopted | New Standards Issued But Not Yet Adopted Revenue from Contracts with Customers This accounting standard was issued to clarify the principles for recognizing revenue and to develop a common standard that would remove inconsistencies in revenue requirements; improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets; and provide improved disclosures. The guidance provides a five-step model to be used for recognizing revenue for the transfer of promised goods and services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The update was originally to be effective for annual and interim reporting periods beginning after December 15, 2016; however, the Financial Accounting Standards Board issued new guidance deferring the effective date by one year to periods beginning after December 31, 2017. Early application will be permitted as of the original effective date. We are currently analyzing the impact of this standard on our financial statements. Amendments to the Consolidation Analysis This standard was issued to respond to concerns regarding the current accounting for consolidation of certain legal entities. Under the new standard, all legal entities are subject to reevaluation under a revised consolidation model which will determine whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities; eliminate the presumption that a general partner should consolidate a limited partnership; affect the consolidation analysis of reporting entities that are involved with VIEs and provide a scope exception from consolidation guidance for reporting entities with interests in certain legal entities who must comply with other requirements. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We are currently analyzing the impact of this standard on our financial statements. Simplifying the Presentation of Debt Issuance Costs This standard was issued to simplify presentation of debt issuance costs. The standard will require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by this standard. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We do not expect the impact of adoption of this standard to be material to our Condensed Consolidated Balance Sheets. |
Power [Member] | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |
New Standards Issued But Not Yet Adopted | New Standards Issued But Not Yet Adopted Revenue from Contracts with Customers This accounting standard was issued to clarify the principles for recognizing revenue and to develop a common standard that would remove inconsistencies in revenue requirements; improve comparability of revenue recognition practices across entities, industries, jurisdictions and capital markets; and provide improved disclosures. The guidance provides a five-step model to be used for recognizing revenue for the transfer of promised goods and services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. The update was originally to be effective for annual and interim reporting periods beginning after December 15, 2016; however, the Financial Accounting Standards Board issued new guidance deferring the effective date by one year to periods beginning after December 31, 2017. Early application will be permitted as of the original effective date. We are currently analyzing the impact of this standard on our financial statements. Amendments to the Consolidation Analysis This standard was issued to respond to concerns regarding the current accounting for consolidation of certain legal entities. Under the new standard, all legal entities are subject to reevaluation under a revised consolidation model which will determine whether limited partnerships and similar legal entities are variable interest entities (VIEs) or voting interest entities; eliminate the presumption that a general partner should consolidate a limited partnership; affect the consolidation analysis of reporting entities that are involved with VIEs and provide a scope exception from consolidation guidance for reporting entities with interests in certain legal entities who must comply with other requirements. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We are currently analyzing the impact of this standard on our financial statements. Simplifying the Presentation of Debt Issuance Costs This standard was issued to simplify presentation of debt issuance costs. The standard will require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by this standard. The update is effective for annual and interim reporting periods beginning after December 15, 2015. We do not expect the impact of adoption of this standard to be material to our Condensed Consolidated Balance Sheets. |
Financing Receivables (Tables)
Financing Receivables (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
PSE And G [Member] | |
Schedule of Financial Receivables [Line Items] | |
Schedule Of Credit Risk Profile Based On Payment Activity | Credit Risk Profile Based on Payment Activity As of As of Consumer Loans September 30, December 31, Millions Commercial/Industrial $ 180 $ 188 Residential 13 13 Total $ 193 $ 201 |
Energy Holdings [Member] | |
Schedule of Financial Receivables [Line Items] | |
Schedule Of Gross And Net Lease Investment | The following table shows Energy Holdings’ gross and net lease investment as of September 30, 2015 and December 31, 2014 , respectively. As of As of September 30, December 31, Millions Lease Receivables (net of Non-Recourse Debt) $ 631 $ 691 Estimated Residual Value of Leased Assets 519 525 Unearned and Deferred Income (368 ) (380 ) Gross Investment in Leases 782 836 Deferred Tax Liabilities (706 ) (738 ) Net Investment in Leases $ 76 $ 98 |
Schedule Of Lease Receivables, Net Of Nonrecourse Debt, Associated With Leveraged Lease Portfolio Based On Counterparty Credit Rating | Lease Receivables, Net of Non-Recourse Debt Counterparties’ Credit Rating (Standard & Poor's (S&P)) As of As of September 30, 2015 September 30, 2015 Millions AA $ 17 BBB+ — BBB- 316 BB- 134 B- 164 Total $ 631 |
Schedule Of Assets Under Lease Receivables | A more detailed description of such assets under lease, as of September 30, 2015 , is presented in the following table. Asset Location Gross Investment % Owned Total Fuel Type Counter-parties’ S&P Credit Ratings As of September 30, 2015 (A) Counterparty Millions MW Powerton Station Units 5 and 6 IL $ 134 64 % 1,538 Coal BB- NRG Energy, Inc. Joliet Station Units 7 and 8 IL $ 84 64 % 1,044 Coal BB- NRG Energy, Inc. Keystone Station Units 1 and 2 PA $ 121 17 % 1,711 Coal B- NRG REMA, LLC Conemaugh Station Units 1 and 2 PA $ 121 17 % 1,711 Coal B- NRG REMA, LLC Shawville Station Units 1, 2, 3 and 4 PA $ 113 100 % 603 Coal B- NRG REMA, LLC |
Available-for-Sale Securities (
Available-for-Sale Securities (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Schedule of Available-for-sale Securities [Line Items] | |
Fair Values And Gross Unrealized Gains And Losses For The Securities Held In The NDT Fund | The following tables show the fair values and gross unrealized gains and losses for the securities held in the NDT Fund. As of September 30, 2015 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 667 $ 176 $ (18 ) $ 825 Debt Securities Government Obligations 445 10 (1 ) 454 Other Debt Securities 402 6 (7 ) 401 Total Debt Securities 847 16 (8 ) 855 Other Securities 35 — — 35 Total NDT Available-for-Sale Securities $ 1,549 $ 192 $ (26 ) $ 1,715 As of December 31, 2014 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 685 $ 220 $ (8 ) $ 897 Debt Securities Government Obligations 430 9 (1 ) 438 Other Debt Securities 333 9 (3 ) 339 Total Debt Securities 763 18 (4 ) 777 Other Securities 106 — — 106 Total NDT Available-for-Sale Securities $ 1,554 $ 238 $ (12 ) $ 1,780 |
Schedule Of Accounts Receivable And Accounts Payable in the NDT Funds | The amounts in the preceding tables do not include receivables and payables for NDT Fund transactions which have not settled at the end of each period. Such amounts are included in Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets as shown in the following table. As of As of September 30, December 31, Millions Accounts Receivable $ 10 $ 10 Accounts Payable $ 4 $ 2 |
Value Of Securities That Have Been In An Unrealized Loss Position For Less Than And Greater Than 12 Months | The following table shows the value of securities in the NDT Fund that have been in an unrealized loss position for less than and greater than 12 months. As of September 30, 2015 As of December 31, 2014 Less Than 12 Months Greater Than 12 Months Less Than 12 Months Greater Than 12 Months Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Millions Equity Securities (A) $ 143 $ (18 ) $ 1 $ — $ 162 $ (8 ) $ 1 $ — Debt Securities Government Obligations (B) 90 (1 ) 15 — 95 — 28 (1 ) Other Debt Securities (C) 164 (5 ) 29 (2 ) 99 (1 ) 30 (2 ) Total Debt Securities 254 (6 ) 44 (2 ) 194 (1 ) 58 (3 ) NDT Available-for-Sale Securities $ 397 $ (24 ) $ 45 $ (2 ) $ 356 $ (9 ) $ 59 $ (3 ) (A) Equity Securities—Investments in marketable equity securities within the NDT Fund are primarily in common stocks within a broad range of industries and sectors. The unrealized losses are distributed over a broad range of securities with limited impairment durations. Power does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (B) Debt Securities (Government)—Unrealized losses on Power’s NDT investments in United States Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. Since these investments are guaranteed by the United States government or an agency of the United States government, it is not expected that these securities will settle for less than their amortized cost basis, since Power does not intend to sell nor will it be more-likely-than-not required to sell. Power does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (C) Debt Securities (Other)—Power’s investments in corporate bonds, collateralized mortgage obligations, asset-backed securities and municipal government obligations are limited to investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since Power does not intend to sell these securities nor will it be more-likely-than-not required to sell, Power does not consider these debt securities to be other-than-temporarily impaired as of September 30, 2015 . |
Proceeds From The Sales Of And The Net Realized Gains On Securities In The NDT Funds And Rabbi Trusts | Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions Proceeds from NDT Fund Sales (A) $ 215 $ 221 $ 1,037 $ 779 Net Realized Gains (Losses) on NDT Fund: Gross Realized Gains 14 45 47 101 Gross Realized Losses (11 ) (3 ) (24 ) (12 ) Net Realized Gains (Losses) on NDT Fund $ 3 $ 42 $ 23 $ 89 (A) Includes activity in accounts related to the liquidation of funds being transitioned to new managers |
Amount Of Available-For-Sale Debt Securities By Maturity Periods | The NDT available-for-sale debt securities held as of September 30, 2015 had the following maturities: Time Frame Fair Value Millions Less than one year $ 8 1 - 5 years 236 6 - 10 years 201 11 - 15 years 51 16 - 20 years 51 Over 20 years 308 Total NDT Available-for-Sale Debt Securities $ 855 |
Rabbi Trust [Member] | |
Schedule of Available-for-sale Securities [Line Items] | |
Value Of Securities That Have Been In An Unrealized Loss Position For Less Than And Greater Than 12 Months | The following table shows the value of securities in the Rabbi Trust Fund that have been in an unrealized loss position for less than and greater than 12 months. As of September 30, 2015 As of December 31, 2014 Less Than 12 Months Greater Than 12 Months Less Than 12 Months Greater Than 12 Months Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Fair Value Gross Unrealized Losses Millions Equity Securities (A) $ — $ — $ — $ — $ — $ — $ — $ — Debt Securities Government Obligations (B) 47 (2 ) 2 — 2 — — — Other Debt Securities (C) 41 (1 ) 9 — 24 — — — Total Debt Securities 88 (3 ) 11 — 26 — — — Rabbi Trust Available-for-Sale Securities $ 88 $ (3 ) $ 11 $ — $ 26 $ — $ — $ — (A) Equity Securities—Investments in marketable equity securities within the Rabbi Trust Fund are through a mutual fund which invests primarily in common stocks within a broad range of industries and sectors. (B) Debt Securities (Government)—Unrealized losses on PSEG’s Rabbi Trust investments in United States Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. Since these investments are guaranteed by the United States government or an agency of the United States government, it is not expected that these securities will settle for less than their amortized cost basis, since PSEG does not intend to sell nor will it be more-likely-than-not required to sell. PSEG does not consider these securities to be other-than-temporarily impaired as of September 30, 2015 . (C) Debt Securities (Other)—PSEG’s investments in corporate bonds, collateralized mortgage obligations, asset-backed securities and municipal government obligations are limited to investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since PSEG does not intend to sell these securities nor will it be more-likely-than-not required to sell, PSEG does not consider these debt securities to be other-than-temporarily impaired as of September 30, 2015 . |
Securities Held In The Rabbi Trusts | The following tables show the fair values, gross unrealized gains and losses and amortized cost basis for the securities held in the Rabbi Trust. As of September 30, 2015 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 11 $ 9 $ — $ 20 Debt Securities Government Obligations 106 1 (1 ) 106 Other Debt Securities 86 — (2 ) 84 Total Debt Securities 192 1 (3 ) 190 Other Securities 1 — — 1 Total Rabbi Trust Available-for-Sale Securities $ 204 $ 10 $ (3 ) $ 211 As of December 31, 2014 Cost Gross Unrealized Gains Gross Unrealized Losses Fair Value Millions Equity Securities $ 12 $ 11 $ — $ 23 Debt Securities Government Obligations 89 2 — 91 Other Debt Securities 74 1 — 75 Total Debt Securities 163 3 — 166 Other Securities 2 — — 2 Total Rabbi Trust Available-for-Sale Securities $ 177 $ 14 $ — $ 191 |
Schedule of Accounts Receivable and Accounts Payable in the Rabbi Trust Funds [Table Text Block] | The amounts in the preceding tables do not include receivables and payables for Rabbi Trust Fund transactions which have not settled at the end of each period. Such amounts are included in Accounts Receivable and Accounts Payable on the Condensed Consolidated Balance Sheets as shown in the following table. As of As of September 30, December 31, Millions Accounts Receivable $ 1 $ 1 Accounts Payable $ 1 $ — |
Proceeds From The Sales Of And The Net Realized Gains On Securities In The NDT Funds And Rabbi Trusts | The proceeds from the sales of and the net realized gains (losses) on securities in the Rabbi Trust Fund were: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions Proceeds from Rabbi Trust Sales (A) $ 20 $ 419 $ 83 $ 445 Net Realized Gains (Losses) on Rabbi Trust: Gross Realized Gains $ — $ 2 $ 2 $ 4 Gross Realized Losses (1 ) (2 ) (1 ) (3 ) Net Realized Gains (Losses) on Rabbi Trust $ (1 ) $ — $ 1 $ 1 (A) Includes activity in accounts related to the liquidation of funds being transitioned to new managers |
Amount Of Available-For-Sale Debt Securities By Maturity Periods | The Rabbi Trust available-for-sale debt securities held as of September 30, 2015 had the following maturities: Time Frame Fair Value Millions Less than one year $ 5 1 - 5 years 49 6 - 10 years 39 11 - 15 years 8 16 - 20 years 9 Over 20 years 80 Total Rabbi Trust Available-for-Sale Debt Securities $ 190 |
Fair Value Of The Rabbi Trusts | The fair value of assets in the Rabbi Trust related to PSEG, PSE&G and Power are detailed as follows: As of As of September 30, December 31, Millions PSE&G $ 42 $ 41 Power 52 45 Other 117 105 Total Rabbi Trust Available-for-Sale Securities $ 211 $ 191 |
Pension and OPEB (Tables)
Pension and OPEB (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Compensation and Retirement Disclosure [Abstract] | |
Components Of Net Periodic Benefit Cost | Pension and OPEB costs for PSEG, except for Servco, are detailed as follows: Pension Benefits OPEB Pension Benefits OPEB Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 2015 2014 Millions Components of Net Periodic Benefit Costs (Credit) Service Cost $ 30 $ 26 $ 5 $ 5 $ 92 $ 78 $ 16 $ 14 Interest Cost 59 58 16 18 176 176 50 52 Expected Return on Plan Assets (103 ) (99 ) (7 ) (7 ) (310 ) (299 ) (22 ) (20 ) Amortization of Net Prior Service Cost (Credit) (5 ) (5 ) (4 ) (4 ) (14 ) (14 ) (11 ) (11 ) Actuarial Loss 38 14 11 6 112 42 32 18 Total Benefit Costs (Credit) $ 19 $ (6 ) $ 21 $ 18 $ 56 $ (17 ) $ 65 $ 53 |
Schedule Of Pension And OPEB Costs | Pension and OPEB costs for PSE&G, Power and PSEG’s other subsidiaries, except for Servco, are detailed as follows: Pension Benefits OPEB Pension Benefits OPEB Three Months Ended Three Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 2015 2014 Millions PSE&G $ 10 $ (4 ) $ 13 $ 12 $ 30 $ (14 ) $ 41 $ 35 Power 5 (2 ) 7 5 16 (5 ) 20 15 Other 4 — 1 1 10 2 4 3 Total Benefit Costs (Credit) $ 19 $ (6 ) $ 21 $ 18 $ 56 $ (17 ) $ 65 $ 53 |
Commitments and Contingent Li31
Commitments and Contingent Liabilities (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Power [Member] | |
Loss Contingencies [Line Items] | |
Face Value Of Outstanding Guarantees, Current Exposure And Margin Positions | The face value of Power's outstanding guarantees, current exposure and margin positions as of September 30, 2015 and December 31, 2014 are shown as follows: As of As of September 30, December 31, Millions Face Value of Outstanding Guarantees $ 1,733 $ 1,814 Exposure under Current Guarantees $ 184 $ 273 Letters of Credit Margin Posted $ 178 $ 159 Letters of Credit Margin Received $ 80 $ 40 Cash Deposited and Received: Counterparty Cash Margin Deposited $ — $ — Counterparty Cash Margin Received $ (44 ) $ (13 ) Net Broker Balance Deposited (Received) $ 4 $ 115 In the Event Power were to Lose its Investment Grade Rating: Additional Collateral that could be Required $ 796 $ 945 Liquidity Available under PSEG’s and Power’s Credit Facilities to Post Collateral $ 3,375 $ 3,495 Additional Amounts Posted: Other Letters of Credit $ 47 $ 45 |
Total Minimum Purchase Commitments | As of September 30, 2015 , the total minimum purchase requirements included in these commitments were as follows: Fuel Type Power's Share of Commitments through 2019 Millions Nuclear Fuel Uranium $ 440 Enrichment $ 345 Fabrication $ 179 Natural Gas $ 1,001 Coal $ 331 |
PSE And G [Member] | |
Loss Contingencies [Line Items] | |
Contract For Anticipated BGS-Fixed Price Eligible Load | The contract prices in dollars per MWh for the BGS-RSCP supply, as well as the approximate load, are as follows: Auction Year 2012 2013 2014 2015 36-Month Terms Ending May 2015 May 2016 May 2017 May 2018 (A) Load (MW) 2,900 2,800 2,800 2,900 $ per MWh $83.88 $92.18 $97.39 $99.54 (A) Prices set for the 2015 BGS auction year became effective on June 1, 2015 when the 2012 BGS auction agreements expired. |
Financial Risk Management Act32
Financial Risk Management Activities (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Schedule Of Derivative Transactions Designated And Effective As Cash Flow Hedges | As of September 30, 2015 and December 31, 2014 , the fair value and the impact on Accumulated Other Comprehensive Income (Loss) associated with accounting hedge activity were as follows: As of As of September 30, December 31, Millions Fair Value of Cash Flow Hedges $ 2 $ 18 Impact on Accumulated Other Comprehensive Income (Loss) (after tax) $ 1 $ 10 |
Schedule Of Derivative Instruments Fair Value In Balance Sheets | As of September 30, 2015 Power (A) PSE&G (A) PSEG (A) Consolidated Cash Flow Hedges Not Designated Not Designated Fair Value Hedges Balance Sheet Location Energy- Related Contracts Energy- Related Contracts Netting (B) Total Power Energy- Related Contracts Interest Rate Swaps Total Derivatives Millions Derivative Contracts Current Assets $ 2 $ 413 $ (268 ) $ 147 $ 4 $ 11 $ 162 Noncurrent Assets — 284 (193 ) 91 — — 91 Total Mark-to-Market Derivative Assets $ 2 $ 697 $ (461 ) $ 238 $ 4 $ 11 $ 253 Derivative Contracts Current Liabilities $ — $ (311 ) $ 241 $ (70 ) $ — $ — $ (70 ) Noncurrent Liabilities — (178 ) 162 (16 ) (7 ) — (23 ) Total Mark-to-Market Derivative (Liabilities) $ — $ (489 ) $ 403 $ (86 ) $ (7 ) $ — $ (93 ) Total Net Mark-to-Market Derivative Assets (Liabilities) $ 2 $ 208 $ (58 ) $ 152 $ (3 ) $ 11 $ 160 As of December 31, 2014 Power (A) PSE&G (A) PSEG (A) Consolidated Cash Flow Hedges Not Designated Not Designated Fair Value Hedges Balance Sheet Location Energy- Related Contracts Energy- Related Contracts Netting (B) Total Power Energy- Related Contracts Interest Rate Swaps Total Derivatives Millions Derivative Contracts Current Assets $ 18 $ 597 $ (408 ) $ 207 $ 18 $ 15 $ 240 Noncurrent Assets — 171 (109 ) 62 8 7 77 Total Mark-to-Market Derivative Assets $ 18 $ 768 $ (517 ) $ 269 $ 26 $ 22 $ 317 Derivative Contracts Current Liabilities $ — $ (568 ) $ 436 $ (132 ) $ — $ — $ (132 ) Noncurrent Liabilities — (138 ) 105 (33 ) — — (33 ) Total Mark-to-Market Derivative (Liabilities) $ — $ (706 ) $ 541 $ (165 ) $ — $ — $ (165 ) Total Net Mark-to-Market Derivative Assets (Liabilities) $ 18 $ 62 $ 24 $ 104 $ 26 $ 22 $ 152 (A) Substantially all of Power's and PSEG's derivative instruments are contracts subject to master netting agreements. Contracts not subject to master netting or similar agreements are immaterial and did not have any collateral posted or received as of September 30, 2015 and December 31, 2014 . PSE&G does not have any derivative contracts subject to master netting or similar agreements. (B) Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral received or posted that has been allocated to derivative positions, where the right of offset exists, has been offset on the Condensed Consolidated Balance Sheets. As of September 30, 2015 and December 31, 2014 , net cash collateral (received) paid of $(58) million and $24 million , respectively, were netted against the corresponding net derivative contract positions. Of the $(58) million as of September 30, 2015 , $(32) million and $(38) million of cash collateral were netted against current assets and noncurrent assets, respectively, and $5 million and $7 million were netted against current liabilities and noncurrent liabilities, respectively. Of the $24 million as of December 31, 2014 , $(4) million and $(8) million were netted against current assets and noncurrent assets, respectively, and $32 million and $4 million were netted against current liabilities and noncurrent liabilities, respectively. |
Schedule Of Derivative Instruments Designated As Cash Flow Hedges | The following shows the effect on the Condensed Consolidated Statements of Operations and on Accumulated Other Comprehensive Income (AOCI) of derivative instruments designated as cash flow hedges for the three months ended September 30, 2015 and 2014 . Derivatives in Cash Flow Hedging Relationships Amount of Pre-Tax Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) Location of Pre-Tax Gain (Loss) Reclassified from AOCI into Income Amount of Pre-Tax Gain (Loss) Reclassified from AOCI into Income (Effective Portion) Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Three Months Ended Three Months Ended Three Months Ended September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 Millions PSEG Energy-Related Contracts $ 1 $ 3 Operating Revenues $ — $ 1 Operating Revenues $ — $ — Total PSEG $ 1 $ 3 $ — $ 1 $ — $ — Power Energy-Related Contracts $ 1 $ 3 Operating Revenues $ — $ 1 Operating Revenues $ — $ — Total Power $ 1 $ 3 $ — $ 1 $ — $ — The following shows the effect on the Condensed Consolidated Statements of Operations and on Accumulated Other Comprehensive Income (AOCI) of derivative instruments designated as cash flow hedges for the nine months ended September 30, 2015 and 2014 . Derivatives in Cash Flow Hedging Relationships Amount of Pre-Tax Gain (Loss) Recognized in AOCI on Derivatives (Effective Portion) Location of Pre-Tax Gain (Loss) Reclassified from AOCI into Income Amount of Pre-Tax Gain (Loss) Reclassified from AOCI into Income (Effective Portion) Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) Nine Months Ended Nine Months Ended Nine Months Ended September 30, September 30, September 30, 2015 2014 2015 2014 2015 2014 Millions PSEG Energy-Related Contracts $ 2 $ (4 ) Operating Revenues $ 17 $ (11 ) Operating Revenues $ — $ — Total PSEG $ 2 $ (4 ) $ 17 $ (11 ) $ — $ — Power Energy-Related Contracts $ 2 $ (4 ) Operating Revenues $ 17 $ (11 ) Operating Revenues $ — $ — Total Power $ 2 $ (4 ) $ 17 $ (11 ) $ — $ — |
Schedule of Derivative Instruments, Effect on Other Comprehensive Income (Loss) [Table Text Block] | The following reconciles the Accumulated Other Comprehensive Income for derivative activity included in the Accumulated Other Comprehensive Loss of PSEG on a pre-tax and after-tax basis. Accumulated Other Comprehensive Income Pre-Tax After-Tax Millions Balance as of December 31, 2014 $ 17 $ 10 Gain Recognized in AOCI 1 1 Less: Gain Reclassified into Income (17 ) (10 ) Balance as of June 30, 2015 $ 1 $ 1 Gain Recognized in AOCI 1 — — Less: Gain Reclassified into Income — — Balance as of September 30, 2015 $ 2 $ 1 |
Schedule Of Derivative Instruments Not Designated As Hedging Instruments And Impact On Results Of Operations | The following shows the effect on the Condensed Consolidated Statements of Operations of derivative instruments not designated as hedging instruments or as normal purchases and sales for the three months and nine months ended September 30, 2015 and 2014 . Derivatives Not Designated as Hedges Location of Pre-Tax Gain (Loss) Recognized in Income on Derivatives Pre-Tax Gain (Loss) Recognized in Income on Derivatives Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 Millions PSEG and Power Energy-Related Contracts Operating Revenues $ 154 $ 93 $ 202 $ (759 ) Energy-Related Contracts Energy Costs (4 ) (12 ) (4 ) 65 Total PSEG and Power $ 150 $ 81 $ 198 $ (694 ) |
Schedule Of Gross Volume, On Absolute Value Basis For Derivative Contracts | The following reflects the gross volume, on an absolute value basis, of derivatives as of September 30, 2015 and December 31, 2014 . Type Notional Total PSEG Power PSE&G Millions As of September 30, 2015 Natural Gas Dth 193 — 154 39 Electricity MWh 291 — 291 — Financial Transmission Rights (FTRs) MWh 21 — 21 — Interest Rate Swaps U.S. Dollars 850 850 — — As of December 31, 2014 Natural Gas Dth 274 — 216 58 Electricity MWh 310 — 310 — FTRs MWh 15 — 15 — Interest Rate Swaps U.S. Dollars 850 850 — — |
Power [Member] | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |
Schedule Providing Credit Risk From Others, Net Of Collateral | The following table provides information on Power’s credit risk from others, net of cash collateral, as of September 30, 2015 . It further delineates that exposure by the credit rating of the counterparties and provides guidance on the concentration of credit risk to individual counterparties and an indication of the quality of Power’s credit risk by credit rating of the counterparties. Rating Current Exposure Securities Held as Collateral Net Exposure Number of Counterparties >10% Net Exposure of Counterparties >10% Millions Millions Investment Grade—External Rating $ 348 $ 118 $ 230 2 $ 127 (A) Non-Investment Grade—External Rating 1 — 1 — — Investment Grade—No External Rating 11 — 11 — — Non-Investment Grade—No External Rating 4 — 4 — — Total $ 364 $ 118 $ 246 2 $ 127 (A) Represents net exposure of $87 million with PSE&G. The remaining net exposure of $40 million is with a non- affiliated power purchaser which is an investment grade counterparty. |
Fair Value Measurements (Tables
Fair Value Measurements (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Fair Value Disclosures [Abstract] | |
PSEG's, Power's And PSE&G's Respective Assets And (Liabilities) Measured At Fair Value On A Recurring Basis | The following tables present information about PSEG’s, PSE&G’s and Power's respective assets and (liabilities) measured at fair value on a recurring basis as of September 30, 2015 and December 31, 2014 , including the fair value measurements and the levels of inputs used in determining those fair values. Amounts shown for PSEG include the amounts shown for PSE&G and Power. Recurring Fair Value Measurements as of September 30, 2015 Description Total Netting (E) Quoted Market Prices for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Millions PSEG Assets: Cash Equivalents (A) $ 226 $ — $ 226 $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 242 $ (461 ) $ — $ 694 $ 9 Interest Rate Swaps (C) $ 11 $ — $ — $ 11 $ — NDT Fund (D) Equity Securities $ 825 $ — $ 824 $ 1 $ — Debt Securities—Govt Obligations $ 454 $ — $ — $ 454 $ — Debt Securities—Other $ 401 $ — $ — $ 401 $ — Other Securities $ 35 $ — $ 35 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 20 $ — $ 20 $ — $ — Debt Securities—Govt Obligations $ 106 $ — $ — $ 106 $ — Debt Securities—Other $ 84 $ — $ — $ 84 $ — Other Securities $ 1 $ — $ 1 $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (93 ) $ 403 $ — $ (489 ) $ (7 ) PSE&G Assets: Cash Equivalents (A) $ — $ — $ — $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 4 $ — $ — $ — $ 4 Rabbi Trust (D) Equity Securities—Mutual Funds $ 4 $ — $ 4 $ — $ — Debt Securities—Govt Obligations $ 21 $ — $ — $ 21 $ — Debt Securities—Other $ 17 $ — $ — $ 17 $ — Other Securities $ — $ — $ — $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (7 ) $ — $ — $ — $ (7 ) Power Assets: Derivative Contracts: Energy-Related Contracts (B) $ 238 $ (461 ) $ — $ 694 $ 5 NDT Fund (D) Equity Securities $ 825 $ — $ 824 $ 1 $ — Debt Securities—Govt Obligations $ 454 $ — $ — $ 454 $ — Debt Securities—Other $ 401 $ — $ — $ 401 $ — Other Securities $ 35 $ — $ 35 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 26 $ — $ — $ 26 $ — Debt Securities—Other $ 21 $ — $ — $ 21 $ — Other Securities $ — $ — $ — $ — $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (86 ) $ 403 $ — $ (489 ) $ — Recurring Fair Value Measurements as of December 31, 2014 Description Total Netting (E) Quoted Market Prices for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Millions PSEG Assets: Cash Equivalents (A) $ 365 $ — $ 365 $ — $ — Derivative Contracts: Energy-Related Contracts (B) $ 295 $ (517 ) $ — $ 774 $ 38 Interest Rate Swaps (C) $ 22 $ — $ — $ 22 $ — NDT Fund (D) Equity Securities $ 897 $ — $ 896 $ 1 $ — Debt Securities—Govt Obligations $ 438 $ — $ — $ 438 $ — Debt Securities—Other $ 339 $ — $ — $ 339 $ — Other Securities $ 106 $ — $ 106 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 23 $ — $ 23 $ — $ — Debt Securities—Govt Obligations $ 91 $ — $ — $ 91 $ — Debt Securities—Other $ 75 $ — $ — $ 75 $ — Other Securities $ 2 $ — $ — $ 2 $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (165 ) $ 541 $ — $ (705 ) $ (1 ) PSE&G Assets: Cash Equivalents (A) $ 294 $ — $ 294 $ — $ — Derivative Contracts: Energy Related Contracts (B) $ 26 $ — $ — $ — $ 26 Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 20 $ — $ — $ 20 $ — Debt Securities—Other $ 16 $ — $ — $ 16 $ — Other Securities $ — $ — $ — $ — $ — Power Assets: Derivative Contracts: Energy-Related Contracts (B) $ 269 $ (517 ) $ — $ 774 $ 12 NDT Fund (D) Equity Securities $ 897 $ — $ 896 $ 1 $ — Debt Securities—Govt Obligations $ 438 $ — $ — $ 438 $ — Debt Securities—Other $ 339 $ — $ — $ 339 $ — Other Securities $ 106 $ — $ 106 $ — $ — Rabbi Trust (D) Equity Securities—Mutual Funds $ 5 $ — $ 5 $ — $ — Debt Securities—Govt Obligations $ 21 $ — $ — $ 21 $ — Debt Securities—Other $ 18 $ — $ — $ 18 $ — Other Securities $ 1 $ — $ — $ 1 $ — Liabilities: Derivative Contracts: Energy-Related Contracts (B) $ (165 ) $ 541 $ — $ (705 ) $ (1 ) (A) Represents money market mutual funds. (B) Level 2—Fair values for energy-related contracts are obtained primarily using a market-based approach. Most derivative contracts (forward purchase or sale contracts and swaps) are valued using the average of the bid/ask midpoints from multiple broker or dealer quotes or auction prices. Prices used in the valuation process are also corroborated independently by management to determine that values are based on actual transaction data or, in the absence of transactions, bid and offers for the day. Examples may include certain exchange and non-exchange traded capacity and electricity contracts and natural gas physical or swap contracts based on market prices, basis adjustments and other premiums where adjustments and premiums are not considered significant to the overall inputs. Level 3—For energy-related contracts, which include more complex agreements where limited observable inputs or pricing information are available, modeling techniques are employed using assumptions reflective of contractual terms, current market rates, forward price curves, discount rates and risk factors, as applicable. Fair values of other energy contracts may be based on broker quotes that we cannot corroborate with actual market transaction data. (C) Interest rate swaps are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment. (D) The NDT Fund maintains investments in various equity and fixed income securities classified as “available for sale.” The Rabbi Trust maintains investments in an S&P 500 index fund and various fixed income securities classified as “available for sale.” These securities are generally valued with prices that are either exchange provided (equity securities) or market transactions for comparable securities and/or broker quotes (fixed income securities). Level 1—Investments in marketable equity securities within the NDT Fund are primarily investments in common stocks across a broad range of industries and sectors. Most equity securities are priced utilizing the principal market close price or, in some cases, midpoint, bid or ask price. Certain open-ended mutual funds with mainly short-term investments are valued based on unadjusted quoted prices in active markets. The Rabbi Trust equity index fund is valued based on quoted prices in an active market. Level 2—NDT and Rabbi Trust fixed income securities are limited to investment grade corporate bonds, collateralized mortgage obligations, asset backed securities and government obligations or Federal Agency asset-backed securities with a wide range of maturities. Since many fixed income securities do not trade on a daily basis, they are priced using an evaluated pricing methodology that varies by asset class and reflects observable market information such as the most recent exchange price or quoted bid for similar securities. Market-based standard inputs typically include benchmark yields, reported trades, broker/dealer quotes and issuer spreads. Certain short-term investments are valued using observable market prices or market parameters such as time-to-maturity, coupon rate, quality rating and current yield. (E) Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral received or posted that has been allocated to derivative positions, where the right of offset exists, has been offset in the Condensed Consolidated Balance Sheets. As of September 30, 2015 , net cash collateral (received) paid of $(58) million , was netted against the corresponding net derivative contract positions. Of the $(58) million as of September 30, 2015 , $(70) million of cash collateral was netted against assets, and $12 million was netted against liabilities. As of December 31, 2014 , net cash collateral (received) paid of $24 million , was netted against the corresponding net derivative contract positions. Of the $24 million as of December 31, 2014 , $(12) million of cash collateral was netted against assets, and $36 million was netted against liabilities. |
Schedule of Quantitative Information About Level 3 Fair Value Measurements | The following tables provide details surrounding significant Level 3 valuations as of September 30, 2015 and December 31, 2014 . Quantitative Information About Level 3 Fair Value Measurements Significant Fair Value as of Valuation Unobservable Commodity Level 3 Position September 30, 2015 Technique(s) Input Range Assets (Liabilities) Millions PSE&G Gas Natural Gas Supply Contracts $ 4 $ (7 ) Discounted Cash Flow Transportation Costs $0.60 to $0.90/dekatherm Total PSE&G $ 4 $ (7 ) Power Electricity Electric Load Contracts $ 4 $ — Discounted Cash flow Historic Load Variability 0% to +10% Other Various (A) 1 — Total Power $ 5 $ — Total PSEG $ 9 $ (7 ) Quantitative Information About Level 3 Fair Value Measurements Significant Fair Value as of Valuation Unobservable Commodity Level 3 Position December 31, 2014 Technique(s) Input Range Assets (Liabilities) Millions PSE&G Gas Natural Gas Supply Contracts $ 26 $ — Discounted Cash Flow Transportation Costs $0.70 to $1/dekatherm Total PSE&G $ 26 $ — Power Electricity Electric Load Contracts $ 12 $ (1 ) Discounted Cash Flow Historic Load Variability 0% to +10% Other Various (B) — — Total Power $ 12 $ (1 ) Total PSEG $ 38 $ (1 ) (A) Includes long-term electric positions which were immaterial as of September 30, 2015 . (B) Includes gas supply positions and long-term electric capacity positions which were immaterial as of December 31, 2014 . |
Changes In Level 3 Assets And (Liabilities) Measured At Fair Value On A Recurring Basis | A reconciliation of the beginning and ending balances of Level 3 derivative contracts and securities for the three months and nine months ended September 30, 2015 and September 30, 2014 , respectively, follows: Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis for the Three Months and Nine Months Ended September 30, 2015 Three Months Ended September 30, 2015 Total Gains or (Losses) Realized/Unrealized Description Balance as of July 1, 2015 Included in Income (A) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out Balance as of September 30, 2015 Millions PSEG Net Derivative Assets (Liabilities) $ 8 $ 4 $ (8 ) $ — $ (2 ) $ — $ 2 PSE&G Net Derivative Assets (Liabilities) $ 5 $ — $ (8 ) $ — $ — $ — $ (3 ) Power Net Derivative Assets (Liabilities) $ 3 $ 4 $ — $ — $ (2 ) $ — $ 5 Nine Months Ended September 30, 2015 Total Gains or (Losses) Realized/Unrealized Description Balance as of January 1, 2015 Included in Income (A) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out Balance as of September 30, 2015 Millions PSEG Net Derivative Assets (Liabilities) $ 37 $ 12 $ (29 ) $ — $ (18 ) $ — $ 2 PSE&G Net Derivative Assets (Liabilities) $ 26 $ — $ (29 ) $ — $ — $ — $ (3 ) Power Net Derivative Assets (Liabilities) $ 11 $ 12 $ — $ — $ (18 ) $ — $ 5 Changes in Level 3 Assets and (Liabilities) Measured at Fair Value on a Recurring Basis for the Three Months and Nine Months Ended September 30, 2014 Three Months Ended September 30, 2014 Total Gains or (Losses) Realized/Unrealized Description Balance as of July 1, 2014 Included in Income (E) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out (D) Balance as of September 30, 2014 Millions PSEG Net Derivative Assets (Liabilities) $ 13 $ (8 ) $ (9 ) $ — $ (4 ) $ — $ (8 ) PSE&G Net Derivative Assets (Liabilities) $ 22 $ — $ (9 ) $ — $ — $ — $ 13 Power Net Derivative Assets (Liabilities) $ (9 ) $ (8 ) $ — $ — $ (4 ) $ — $ (21 ) Nine Months Ended September 30, 2014 Total Gains or (Losses) Realized/Unrealized Description Balance as of January 1, 2014 Included in Income (E) Included in Regulatory Assets/ Liabilities (B) Purchases (Sales) Issuances/ Settlements (C) Transfers In/Out (D) Balance as of September 30, 2014 Millions PSEG Net Derivative Assets (Liabilities) $ 88 $ (66 ) $ (81 ) $ — $ 54 $ (3 ) $ (8 ) PSE&G Net Derivative Assets (Liabilities) $ 94 $ — $ (81 ) $ — $ — $ — $ 13 Power Net Derivative Assets (Liabilities) $ (6 ) $ (66 ) $ — $ — $ 54 $ (3 ) $ (21 ) (A) PSEG’s and Power’s gains and losses attributable to changes in net derivative assets and liabilities includes $4 million and $12 million in Operating Income for the three months and nine months ended September 30, 2015 , respectively. Of the $4 million in Operating Income, $3 million is unrealized. Of the $12 million in Operating Income, $(6) million is unrealized. (B) Mainly includes gains/losses on PSE&G’s derivative contracts that are not included in either earnings or Other Comprehensive Income, as they are deferred as a Regulatory Asset/Liability and are expected to be recovered from/returned to PSE&G’s customers. (C) Represents $(2) million and $(18) million in settlements for the three months and nine months ended September 30, 2015 . Includes $(4) million and $54 million in settlements for the three months and nine months ended September 30, 2014 . (D) There were no transfers among levels during the three months ended September 30, 2015 and 2014 and the nine months ended September 30, 2015 . During the nine months ended September 30, 2014 , $(3) million of net derivative assets/liabilities were transferred from Level 3 to Level 2 due to more observable pricing for the underlying securities. The transfers were recognized as of the beginning of the quarters in which the transfers first occurred as per PSEG's policy. (E) PSEG’s and Power’s gains and losses attributable to changes in net derivative assets and liabilities include $(8) million and $(66) million in Operating Income for the three months and nine months ended September 30, 2014 , respectively. Of the $(8) million in Operating Income, $(12) million is unrealized. Of the $(66) million in Operating Income, $(11) million is unrealized. |
Schedule of Fair Value of Debt | The estimated fair values were determined using the market quotations or values of instruments with similar terms, credit ratings, remaining maturities and redemptions as of September 30, 2015 and December 31, 2014 . As of As of September 30, 2015 December 31, 2014 Carrying Amount Fair Value Carrying Amount Fair Value Millions Long-Term Debt: PSEG (Parent) (A) $ 7 $ 11 $ 14 $ 22 PSE&G (B) 6,612 7,102 6,312 6,912 Transition Funding (PSE&G) (B) 68 69 251 261 Transition Funding II (PSE&G) (B) — — 8 8 Power - Recourse Debt (B) 2,544 2,856 2,543 2,930 Energy Holdings: Project Level, Non-Recourse Debt (C) 7 7 16 16 Total Long-Term Debt $ 9,238 $ 10,045 $ 9,144 $ 10,149 (A) Fair value represents net offsets to debt resulting from adjustments from interest rate swaps entered into to hedge certain debt at Power. Carrying amount represents such fair value reduced by the unamortized premium resulting from a debt exchange entered into between Power and Energy Holdings. (B) The debt fair valuation is based on the present value of each bond’s future cash flows. The discount rates used in the present value analysis are based on an estimate of new issue bond yields across the treasury curve. When a bond has embedded options, an interest rate model is used to reflect the impact of interest rate volatility into the analysis (primarily Level 2 measurements). (C) Non-recourse project debt is valued as equivalent to the amortized cost and is classified as a Level 3 measurement. |
Other Income and Deductions (Ta
Other Income and Deductions (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Other Income and Expenses [Abstract] | |
Schedule Of Other Income | Other Income PSE&G Power Other (A) Consolidated Millions Three Months Ended September 30, 2015 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 24 $ — $ 24 Allowance for Funds Used During Construction 14 — — 14 Solar Loan Interest 6 — — 6 Other 2 1 — 3 Total Other Income $ 22 $ 25 $ — $ 47 Nine Months Ended September 30, 2015 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 78 $ — $ 78 Allowance for Funds Used During Construction 36 — — 36 Solar Loan Interest 18 — — 18 Gain on Insurance Recovery — 28 — 28 Other 5 3 3 11 Total Other Income $ 59 $ 109 $ 3 $ 171 Three Months Ended September 30, 2014 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 55 $ — $ 55 Allowance for Funds Used During Construction 8 — — 8 Solar Loan Interest 6 — — 6 Other 2 1 3 6 Total Other Income $ 16 $ 56 $ 3 $ 75 Nine Months Ended September 30, 2014 NDT Fund Gains, Interest, Dividend and Other Income $ — $ 133 $ — $ 133 Allowance for Funds Used During Construction 21 — — 21 Solar Loan Interest 18 — — 18 Other 5 2 6 13 Total Other Income $ 44 $ 135 $ 6 $ 185 |
Schedule Of Other Deductions | Other Deductions PSE&G Power Other (A) Consolidated Millions Three Months Ended September 30, 2015 NDT Fund Realized Losses and Expenses $ — $ 13 $ — $ 13 Other — 1 — 1 Total Other Deductions $ — $ 14 $ — $ 14 Nine Months Ended September 30, 2015 NDT Fund Realized Losses and Expenses $ — $ 30 $ — $ 30 Other 2 2 2 6 Total Other Deductions $ 2 $ 32 $ 2 $ 36 Three Months Ended September 30, 2014 NDT Fund Realized Losses and Expenses $ — $ 4 $ — $ 4 Other 2 2 1 5 Total Other Deductions $ 2 $ 6 $ 1 $ 9 Nine Months Ended September 30, 2014 NDT Fund Realized Losses and Expenses $ — $ 18 $ — $ 18 Other 3 7 3 13 Total Other Deductions $ 3 $ 25 $ 3 $ 31 (A) Other consists of activity at PSEG (as parent company), Energy Holdings, Services, PSEG LI and intercompany eliminations. |
Income Taxes (Tables)
Income Taxes (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Income Tax Disclosure [Abstract] | |
Schedule Of Effective Tax Rates | PSEG’s, PSE&G’s and Power's effective tax rates for the three months and nine months ended September 30, 2015 and 2014 were as follows: Three Months Ended Nine Months Ended September 30, September 30, 2015 2014 2015 2014 PSEG 39.4% 37.0% 38.8% 37.8% PSE&G 38.2% 38.5% 38.7% 38.6% Power 40.3% 39.4% 38.6% 38.6% |
Accumulated Other Comprehensi36
Accumulated Other Comprehensive Income (Loss), Net of Tax (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | |
Schedule of Changes in Accumulated Other Comprehensive Income by Component | PSEG Other Comprehensive Income (Loss) Three Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2015 $ 1 $ (395 ) $ 117 $ (277 ) Other Comprehensive Income before Reclassifications — — (46 ) (46 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) — 9 15 24 Net Current Period Other Comprehensive Income (Loss) — 9 (31 ) (22 ) Balance as of September 30, 2015 $ 1 $ (386 ) $ 86 $ (299 ) Other Comprehensive Income (Loss) Three Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2014 $ 1 $ (232 ) $ 158 $ (73 ) Other Comprehensive Income before Reclassifications 2 — (15 ) (13 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (1 ) 3 (15 ) (13 ) Net Current Period Other Comprehensive Income (Loss) 1 3 (30 ) (26 ) Balance as of September 30, 2014 $ 2 $ (229 ) $ 128 $ (99 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2014 $ 10 $ (411 ) $ 118 $ (283 ) Other Comprehensive Income before Reclassifications 1 — (44 ) (43 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (10 ) 25 12 27 Net Current Period Other Comprehensive Income (Loss) (9 ) 25 (32 ) (16 ) Balance as of September 30, 2015 $ 1 $ (386 ) $ 86 $ (299 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2013 $ (2 ) $ (238 ) $ 145 $ (95 ) Other Comprehensive Income before Reclassifications (2 ) — 19 17 Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) 6 9 (36 ) (21 ) Net Current Period Other Comprehensive Income (Loss) 4 9 (17 ) (4 ) Balance as of September 30, 2014 $ 2 $ (229 ) $ 128 $ (99 ) Power Other Comprehensive Income (Loss) Three Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2015 $ 2 $ (337 ) $ 112 $ (223 ) Other Comprehensive Income before Reclassifications — — (43 ) (43 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) — 7 14 21 Net Current Period Other Comprehensive Income (Loss) — 7 (29 ) (22 ) Balance as of September 30, 2015 $ 2 $ (330 ) $ 83 $ (245 ) Other Comprehensive Income (Loss) Three Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of June 30, 2014 $ 2 $ (199 ) $ 153 $ (44 ) Other Comprehensive Income before Reclassifications 2 — (14 ) (12 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (1 ) 2 (16 ) (15 ) Net Current Period Other Comprehensive Income (Loss) 1 2 (30 ) (27 ) Balance as of September 30, 2014 $ 3 $ (197 ) $ 123 $ (71 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2015 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2014 $ 11 $ (351 ) $ 112 $ (228 ) Other Comprehensive Income before Reclassifications 1 — (41 ) (40 ) Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) (10 ) 21 12 23 Net Current Period Other Comprehensive Income (Loss) (9 ) 21 (29 ) (17 ) Balance as of September 30, 2015 $ 2 $ (330 ) $ 83 $ (245 ) Other Comprehensive Income (Loss) Nine Months Ended September 30, 2014 Accumulated Other Comprehensive Income (Loss) Cash Flow Hedges Pension and OPEB Plans Available-for-Sale Securities Total Millions Balance as of December 31, 2013 $ (1 ) $ (204 ) $ 142 $ (63 ) Other Comprehensive Income before Reclassifications (2 ) — 17 15 Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) 6 7 (36 ) (23 ) Net Current Period Other Comprehensive Income (Loss) 4 7 (19 ) (8 ) Balance as of September 30, 2014 $ 3 $ (197 ) $ 123 $ (71 ) |
Reclassifications out of Accumulated Other Comprehensive Income | PSEG Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2015 September 30, 2015 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ — $ — $ — $ 17 $ (7 ) $ 10 Total Cash Flow Hedges — — — 17 (7 ) 10 Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 9 (3 ) 6 Amortization of Actuarial Loss O&M Expense (17 ) 6 (11 ) (51 ) 20 (31 ) Total Pension and OPEB Plans (14 ) 5 (9 ) (42 ) 17 (25 ) Available-for-Sale Securities Realized Gains Other Income 14 (7 ) 7 49 (25 ) 24 Realized Losses Other Deductions (12 ) 5 (7 ) (25 ) 12 (13 ) Other-Than-Temporary Impairments (OTTI) OTTI (30 ) 15 (15 ) (45 ) 22 (23 ) Total Available-for-Sale Securities (28 ) 13 (15 ) (21 ) 9 (12 ) Total $ (42 ) $ 18 $ (24 ) $ (46 ) $ 19 $ (27 ) PSEG Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2014 September 30, 2014 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ 1 $ — $ 1 $ (11 ) $ 5 $ (6 ) Total Cash Flow Hedges 1 — 1 (11 ) 5 (6 ) Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 8 (3 ) 5 Amortization of Actuarial Loss O&M Expense (8 ) 3 (5 ) (22 ) 8 (14 ) Total Pension and OPEB Plans (5 ) 2 (3 ) (14 ) 5 (9 ) Available-for-Sale Securities Realized Gains Other Income 47 (24 ) 23 105 (54 ) 51 Realized Losses Other Deductions (5 ) 2 (3 ) (15 ) 7 (8 ) OTTI OTTI (10 ) 5 (5 ) (14 ) 7 (7 ) Total Available-for-Sale Securities 32 (17 ) 15 76 (40 ) 36 Total $ 28 $ (15 ) $ 13 $ 51 $ (30 ) $ 21 Power Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2015 September 30, 2015 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ — $ — $ — $ 17 $ (7 ) $ 10 Total Cash Flow Hedges — — — 17 (7 ) 10 Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 9 (3 ) 6 Amortization of Actuarial Loss O&M Expense (15 ) 6 (9 ) (45 ) 18 (27 ) Total Pension and OPEB Plans (12 ) 5 (7 ) (36 ) 15 (21 ) Available-for-Sale Securities Realized Gains Other Income 14 (7 ) 7 47 (24 ) 23 Realized Losses Other Deductions (11 ) 5 (6 ) (24 ) 12 (12 ) OTTI OTTI (30 ) 15 (15 ) (45 ) 22 (23 ) Total Available-for-Sale Securities (27 ) 13 (14 ) (22 ) 10 (12 ) Total $ (39 ) $ 18 $ (21 ) $ (41 ) $ 18 $ (23 ) Power Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) to Income Statement Three Months Ended Nine Months Ended Description of Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) Location of Pre-Tax Amount In Statement of Operations September 30, 2014 September 30, 2014 Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Pre-Tax Amount Tax (Expense) Benefit After-Tax Amount Millions Cash Flow Hedges Energy-Related Contracts Operating Revenues $ 1 $ — $ 1 $ (11 ) $ 5 $ (6 ) Total Cash Flow Hedges 1 — 1 (11 ) 5 (6 ) Pension and OPEB Plans Amortization of Prior Service (Cost) Credit O&M Expense 3 (1 ) 2 7 (3 ) 4 Amortization of Actuarial Loss O&M Expense (6 ) 2 (4 ) (18 ) 7 (11 ) Total Pension and OPEB Plans (3 ) 1 (2 ) (11 ) 4 (7 ) Available-for-Sale Securities Realized Gains Other Income 45 (23 ) 22 101 (52 ) 49 Realized Losses Other Deductions (2 ) 1 (1 ) (12 ) 6 (6 ) OTTI OTTI (10 ) 5 (5 ) (14 ) 7 (7 ) Total Available-for-Sale Securities 33 (17 ) 16 75 (39 ) 36 Total $ 31 $ (16 ) $ 15 $ 53 $ (30 ) $ 23 |
Earnings Per Share (EPS) and 37
Earnings Per Share (EPS) and Dividends (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Earnings Per Share [Abstract] | |
Basic And Diluted Earnings Per Share Computation | The following table shows the effect of these stock options, performance units and restricted stock units on the weighted average number of shares outstanding used in calculating diluted EPS. Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 Basic Diluted Basic Diluted Basic Diluted Basic Diluted EPS Numerator (Millions) Net Income $ 439 $ 439 $ 444 $ 444 $ 1,370 $ 1,370 $ 1,042 $ 1,042 EPS Denominator (Millions) Weighted Average Common Shares Outstanding 505 505 506 506 505 505 506 506 Effect of Stock Based Compensation Awards — 3 — 1 — 3 — 1 Total Shares 505 508 506 507 505 508 506 507 EPS Net Income $ 0.87 $ 0.87 $ 0.88 $ 0.87 $ 2.71 $ 2.70 $ 2.06 $ 2.05 |
Dividend Payments On Common Stock | Three Months Ended Nine Months Ended September 30, September 30, Dividend Payments on Common Stock 2015 2014 2015 2014 Per Share $ 0.39 $ 0.37 $ 1.17 $ 1.11 In Millions $ 198 $ 187 $ 592 $ 561 |
Financial Information By Busi38
Financial Information By Business Segments (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Segment Reporting [Abstract] | |
Financial Information By Business Segments | PSE&G Power Other (A) Eliminations (B) Consolidated Millions Three Months Ended September 30, 2015 Total Operating Revenues $ 1,766 $ 1,096 $ 120 $ (294 ) $ 2,688 Net Income (Loss) 222 206 11 — 439 Gross Additions to Long-Lived Assets 716 310 13 — 1,039 Nine Months Ended September 30, 2015 Total Operating Revenues $ 5,234 $ 3,846 $ 326 $ (1,269 ) $ 8,137 Net Income (Loss) 631 707 32 — 1,370 Gross Additions to Long-Lived Assets 1,946 797 39 — 2,782 Three Months Ended September 30, 2014 Total Operating Revenues $ 1,655 $ 1,138 $ 123 $ (275 ) $ 2,641 Net Income (Loss) 200 222 22 — 444 Gross Additions to Long-Lived Assets 497 188 8 — 693 Nine Months Ended September 30, 2014 Total Operating Revenues $ 5,235 $ 3,824 $ 359 $ (1,305 ) $ 8,113 Net Income (Loss) 565 440 37 — 1,042 Gross Additions to Long-Lived Assets 1,493 414 15 — 1,922 As of September 30, 2015 Total Assets $ 22,909 $ 12,314 $ 2,775 $ (1,574 ) $ 36,424 Investments in Equity Method Subsidiaries $ — $ 116 $ 1 $ — $ 117 As of December 31, 2014 Total Assets $ 22,223 $ 12,046 $ 2,799 $ (1,735 ) $ 35,333 Investments in Equity Method Subsidiaries $ — $ 121 $ 2 $ — $ 123 (A) Includes amounts applicable to Energy Holdings and PSEG LI, which are below the quantitative threshold for separate disclosure as reportable segments. Other also includes amounts applicable to PSEG (parent corporation) and Services. (B) Intercompany eliminations, primarily related to intercompany transactions between PSE&G and Power. No gains or losses are recorded on any intercompany transactions; rather, all intercompany transactions are at cost or, in the case of the BGS and BGSS contracts between PSE&G and Power, at rates prescribed by the BPU. For a further discussion of the intercompany transactions between PSE&G and Power, see Note 17. Related-Party Transactions . |
Related-Party Transactions (Tab
Related-Party Transactions (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
PSE And G [Member] | |
Related Party Transaction [Line Items] | |
Schedule Of Related Party Transactions, Revenue | The financial statements for PSE&G include transactions with related parties presented as follows: Three Months Ended Nine Months Ended September 30, September 30, Related-Party Transactions 2015 2014 2015 2014 Millions Billings from Affiliates: Billings from Power primarily through BGS and BGSS (A) $ 294 $ 280 $ 1,287 $ 1,308 Administrative Billings from Services (B) 66 59 197 183 Total Billings from Affiliates $ 360 $ 339 $ 1,484 $ 1,491 |
Schedule Of Related Party Transactions, Payables | As of As of Related-Party Transactions September 30, 2015 December 31, 2014 Millions Receivable from PSEG (C) $ 7 $ 274 Payable to Power (A) $ 158 $ 313 Payable to Services (B) 50 66 Accounts Payable—Affiliated Companies $ 208 $ 379 Working Capital Advances to Services (D) $ 33 $ 33 Long-Term Accrued Taxes Payable $ 165 $ 116 |
Power [Member] | |
Related Party Transaction [Line Items] | |
Schedule Of Related Party Transactions, Revenue | The financial statements for Power include transactions with related parties presented as follows: Three Months Ended Nine Months Ended September 30, September 30, Related-Party Transactions 2015 2014 2015 2014 Millions Billings to Affiliates: Billings to PSE&G primarily through BGS and BGSS (A) $ 294 $ 280 $ 1,287 $ 1,308 Billings from Affiliates: Administrative Billings from Services (B) $ 44 $ 41 $ 135 $ 129 |
Schedule Of Related Party Transactions, Receivables | As of As of Related-Party Transactions September 30, 2015 December 31, 2014 Millions Receivables from PSE&G (A) $ 158 $ 313 Payable to Services (B) $ 26 $ 23 Payable to PSEG (C) 91 95 Accounts Payable—Affiliated Companies $ 117 $ 118 Short-Term Loan Due (to) from Affiliate (E) $ 865 $ 584 Working Capital Advances to Services (D) $ 17 $ 17 Long-Term Accrued Taxes Payable $ 54 $ 41 |
Guarantees of Debt (Tables)
Guarantees of Debt (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Power [Member] | |
Debt Instrument [Line Items] | |
Schedule Of Financial Statements Of Guarantors | Power Guarantor Subsidiaries Other Subsidiaries Consolidating Adjustments Consolidated Millions Three Months Ended September 30, 2015 Operating Revenues $ — $ 1,084 $ 37 $ (25 ) $ 1,096 Operating Expenses 3 692 35 (25 ) 705 Operating Income (Loss) (3 ) 392 2 — 391 Equity Earnings (Losses) of Subsidiaries 220 (2 ) 3 (218 ) 3 Other Income 10 26 — (11 ) 25 Other Deductions — (14 ) — — (14 ) Other-Than-Temporary Impairments — (30 ) — — (30 ) Interest Expense (28 ) (8 ) (5 ) 11 (30 ) Income Tax Benefit (Expense) 7 (148 ) 2 — (139 ) Net Income (Loss) $ 206 $ 216 $ 2 $ (218 ) $ 206 Comprehensive Income (Loss) $ 184 $ 187 $ 2 $ (189 ) $ 184 Nine Months Ended September 30, 2015 Operating Revenues $ — $ 3,811 $ 144 $ (109 ) $ 3,846 Operating Expenses 7 2,610 135 (109 ) 2,643 Operating Income (Loss) (7 ) 1,201 9 — 1,203 Equity Earnings (Losses) of Subsidiaries 755 (4 ) 11 (751 ) 11 Other Income 33 111 — (35 ) 109 Other Deductions (1 ) (31 ) — — (32 ) Other-Than-Temporary Impairments — (45 ) — — (45 ) Interest Expense (90 ) (24 ) (15 ) 35 (94 ) Income Tax Benefit (Expense) 17 (463 ) 1 — (445 ) Net Income (Loss) $ 707 $ 745 $ 6 $ (751 ) $ 707 Comprehensive Income (Loss) $ 690 $ 707 $ 6 $ (713 ) $ 690 Nine Months Ended September 30, 2015 Net Cash Provided By (Used In) Operating Activities $ 435 $ 1,826 $ 66 $ (769 ) $ 1,558 Net Cash Provided By (Used In) Investing Activities $ (656 ) $ (1,382 ) $ (303 ) $ 1,191 $ (1,150 ) Net Cash Provided By (Used In) Financing Activities $ 221 $ (446 ) $ 245 $ (422 ) $ (402 ) Power Guarantor Subsidiaries Other Subsidiaries Consolidating Adjustments Consolidated Millions Three Months Ended September 30, 2014 Operating Revenues $ — $ 1,125 $ 36 $ (23 ) $ 1,138 Operating Expenses 3 772 32 (22 ) 785 Operating Income (Loss) (3 ) 353 4 (1 ) 353 Equity Earnings (Losses) of Subsidiaries 225 (1 ) 4 (224 ) 4 Other Income 9 55 — (8 ) 56 Other Deductions (3 ) (4 ) — 1 (6 ) Other-Than-Temporary Impairments — (10 ) — — (10 ) Interest Expense (24 ) (10 ) (4 ) 7 (31 ) Income Tax Benefit (Expense) 18 (161 ) (1 ) — (144 ) Net Income (Loss) $ 222 $ 222 $ 3 $ (225 ) $ 222 Comprehensive Income (Loss) $ 195 $ 191 $ 3 $ (194 ) $ 195 Nine Months Ended September 30, 2014 Operating Revenues $ — $ 3,781 $ 118 $ (75 ) $ 3,824 Operating Expenses 12 3,079 106 (75 ) 3,122 Operating Income (Loss) (12 ) 702 12 — 702 Equity Earnings (Losses) of Subsidiaries 459 (4 ) 11 (455 ) 11 Other Income 25 135 — (25 ) 135 Other Deductions (7 ) (18 ) — — (25 ) Other-Than-Temporary Impairments — (14 ) — — (14 ) Interest Expense (79 ) (23 ) (14 ) 24 (92 ) Income Tax Benefit (Expense) 54 (329 ) (2 ) — (277 ) Net Income (Loss) $ 440 $ 449 $ 7 $ (456 ) $ 440 Comprehensive Income (Loss) $ 432 $ 433 $ 7 $ (440 ) $ 432 Nine Months Ended September 30, 2014 Net Cash Provided By (Used In) Operating Activities $ 471 $ 1,252 $ 53 $ (666 ) $ 1,110 Net Cash Provided By (Used In) Investing Activities $ 187 $ (559 ) $ (24 ) $ 70 $ (326 ) Net Cash Provided By (Used In) Financing Activities $ (652 ) $ (693 ) $ (29 ) $ 596 $ (778 ) Power Guarantor Subsidiaries Other Subsidiaries Consolidating Adjustments Consolidated Millions As of September 30, 2015 Current Assets $ 4,678 $ 1,786 $ 134 $ (4,374 ) $ 2,224 Property, Plant and Equipment, net 82 6,390 1,435 — 7,907 Investment in Subsidiaries 4,555 349 — (4,904 ) — Noncurrent Assets 264 1,962 133 (176 ) 2,183 Total Assets $ 9,579 $ 10,487 $ 1,702 $ (9,454 ) $ 12,314 Current Liabilities $ 1,581 $ 3,595 $ 772 $ (4,374 ) $ 1,574 Noncurrent Liabilities 458 2,563 355 (176 ) 3,200 Long-Term Debt 1,691 — — — 1,691 Member's Equity 5,849 4,329 575 (4,904 ) 5,849 Total Liabilities and Member's Equity $ 9,579 $ 10,487 $ 1,702 $ (9,454 ) $ 12,314 As of December 31, 2014 Current Assets $ 4,263 $ 2,037 $ 150 $ (4,091 ) $ 2,359 Property, Plant and Equipment, net 81 6,265 1,169 — 7,515 Investment in Subsidiaries 4,516 120 — (4,636 ) — Noncurrent Assets 278 1,952 137 (195 ) 2,172 Total Assets $ 9,138 $ 10,374 $ 1,456 $ (8,922 ) $ 12,046 Current Liabilities $ 883 $ 3,606 $ 786 $ (4,091 ) $ 1,184 Noncurrent Liabilities 454 2,442 360 (195 ) 3,061 Long-Term Debt 2,243 — — — 2,243 Member's Equity 5,558 4,326 310 (4,636 ) 5,558 Total Liabilities and Member's Equity $ 9,138 $ 10,374 $ 1,456 $ (8,922 ) $ 12,046 |
Variable Interest Entities (V41
Variable Interest Entities (VIEs) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | Dec. 31, 2014 | |
Variable Interest Entity [Line Items] | |||||
Operating Revenues | $ 2,688 | $ 2,641 | $ 8,137 | $ 8,113 | |
Operation and Maintenance | 746 | 714 | 2,170 | 2,370 | |
PSE And G [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Maximum exposure to loss | 16 | 16 | $ 16 | ||
Operating Revenues | 1,766 | 1,655 | 5,234 | 5,235 | |
Operation and Maintenance | 391 | 366 | 1,171 | 1,190 | |
Long Island ServCo [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Operating Revenues | 96 | 107 | 262 | 307 | |
Operation and Maintenance | $ 96 | $ 107 | $ 262 | $ 307 |
Rate Filings (Details)
Rate Filings (Details) - PSE And G [Member] $ in Millions | 1 Months Ended | ||||||
Oct. 31, 2015USD ($) | Sep. 30, 2015USD ($) | Jul. 31, 2015USD ($) | Jun. 30, 2015USD ($) | Apr. 30, 2015USD ($)$ / DTH | Mar. 31, 2015$ / DTH | Oct. 01, 2015 | |
Regulatory Assets And Liabilities [Line Items] | |||||||
Requested rate increase (decrease) | $ (6) | ||||||
Self implementing bill credit per therm | $ / DTH | 0.45 | 0.28 | |||||
BGSS revenue reduction | $ 31 | ||||||
Current BGSS rate per therm | 0.45 | ||||||
Proposed BGSS rate per therm | 0.40 | ||||||
Approved capital expenditures for Green Program | 95 | ||||||
Approved administrative expenses for Green Program | 12 | ||||||
Proposed recovery of costs for Electric Green Energy Program | $ 66 | ||||||
Proposed recovery of costs for Gas Green Energy Programs | $ 10 | ||||||
True-up adjustment for transmission formula rate revenues | $ 19 | ||||||
Request for RAC Recovery | 85 | ||||||
Electric Distribution [Member] | |||||||
Regulatory Assets And Liabilities [Line Items] | |||||||
Requested rate increase (decrease) | (17) | ||||||
Electric Distribution [Member] | |||||||
Regulatory Assets And Liabilities [Line Items] | |||||||
Requested rate increase (decrease) | $ (14) | ||||||
Overrecovered Gas Costs Basic Gas Supply Service [Member] | |||||||
Regulatory Assets And Liabilities [Line Items] | |||||||
BGSS revenue reduction | 70 | ||||||
Gas Weather Normalization Deferral [Member] | |||||||
Regulatory Assets And Liabilities [Line Items] | |||||||
Requested rate increase (decrease) | $ 40 | $ 45 | |||||
Subsequent Event [Member] | |||||||
Regulatory Assets And Liabilities [Line Items] | |||||||
Requested rate increase (decrease) | $ (146) |
Financing Receivables (Schedule
Financing Receivables (Schedule Of Credit Risk Profile Based On Payment Activity) (Detail) - PSE And G [Member] - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Concentration Risk [Line Items] | ||
Credit Risk Profile Based on Payment Activity | $ 193 | $ 201 |
Commercial/Industrial [Member] | ||
Concentration Risk [Line Items] | ||
Credit Risk Profile Based on Payment Activity | 180 | 188 |
Residential [Member] | ||
Concentration Risk [Line Items] | ||
Credit Risk Profile Based on Payment Activity | $ 13 | $ 13 |
Financing Receivables (Gross An
Financing Receivables (Gross And Net Lease Investment) (Detail) - Energy Holdings [Member] - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Schedule of Financial Receivables [Line Items] | ||
Lease Receivables (net of Non-Recourse Debt) | $ 631 | $ 691 |
Estimated Residual Value of Leased Assets | 519 | 525 |
Unearned and Deferred Income | (368) | (380) |
Gross Investment in Leases | 782 | 836 |
Deferred Tax Liabilities | (706) | (738) |
Net Investment in Leases | $ 76 | $ 98 |
Financing Receivables (Schedu45
Financing Receivables (Schedule Of Lease Receivables, Net Of Nonrecourse Debt, Associated With Leveraged Lease Portfolio Based On Counterparty Credit Rating) (Detail) - Energy Holdings [Member] - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Schedule of Financial Receivables [Line Items] | ||
Lease Receivables (net of Non-Recourse Debt) | $ 631 | $ 691 |
Standard & Poor's, AA Rating [Member] | ||
Schedule of Financial Receivables [Line Items] | ||
Lease Receivables (net of Non-Recourse Debt) | 17 | |
Standard & Poor's, BBB plus - BBB - Rating [Member] | ||
Schedule of Financial Receivables [Line Items] | ||
Lease Receivables (net of Non-Recourse Debt) | 316 | |
Standard & Poor's, BB- Rating [Member] | ||
Schedule of Financial Receivables [Line Items] | ||
Lease Receivables (net of Non-Recourse Debt) | 134 | |
Standard & Poor's, B- Rating [Member] | ||
Schedule of Financial Receivables [Line Items] | ||
Lease Receivables (net of Non-Recourse Debt) | $ 164 |
Financing Receivables (Narrativ
Financing Receivables (Narrative) (Detail) $ in Millions | Sep. 30, 2015USD ($) |
Schedule of Financial Receivables [Line Items] | |
Lease investment with non-investment grade counterparties, gross | $ 573 |
Lease investment with non-investment grade counterparties, net of deferred taxes | $ (13) |
Financing Receivables (Schedu47
Financing Receivables (Schedule Of Assets Under Lease Receivables) (Detail) $ in Millions | 9 Months Ended |
Sep. 30, 2015USD ($)MW | |
Powerton Station Units 5 And 6 [Member] | |
Schedule of Financial Receivables [Line Items] | |
Location | IL |
Gross Investment | $ 134 |
% Owned | 64.00% |
Total | MW | 1,538 |
Fuel Type | Coal |
Counter-parties’ S&P Credit Ratings As of September 30, 2015 (A) | BB- |
Counterparty | NRG Energy, Inc. |
Joliet Station Units 7 And 8 [Member] | |
Schedule of Financial Receivables [Line Items] | |
Location | IL |
Gross Investment | $ 84 |
% Owned | 64.00% |
Total | MW | 1,044 |
Fuel Type | Coal |
Counter-parties’ S&P Credit Ratings As of September 30, 2015 (A) | BB- |
Counterparty | NRG Energy, Inc. |
Keystone Station Units 1 And 2 [Member] | |
Schedule of Financial Receivables [Line Items] | |
Location | PA |
Gross Investment | $ 121 |
% Owned | 17.00% |
Total | MW | 1,711 |
Fuel Type | Coal |
Counter-parties’ S&P Credit Ratings As of September 30, 2015 (A) | B- |
Counterparty | NRG REMA, LLC |
Conemaugh Station Units 1 And 2 [Member] | |
Schedule of Financial Receivables [Line Items] | |
Location | PA |
Gross Investment | $ 121 |
% Owned | 17.00% |
Total | MW | 1,711 |
Fuel Type | Coal |
Counter-parties’ S&P Credit Ratings As of September 30, 2015 (A) | B- |
Counterparty | NRG REMA, LLC |
Shawville Station Units 1, 2, 3 And 4 [Member] | |
Schedule of Financial Receivables [Line Items] | |
Location | PA |
Gross Investment | $ 113 |
% Owned | 100.00% |
Total | MW | 603 |
Fuel Type | Coal |
Counter-parties’ S&P Credit Ratings As of September 30, 2015 (A) | B- |
Counterparty | NRG REMA, LLC |
Available-For-Sale Securities48
Available-For-Sale Securities (Fair Values And Gross Unrealized Gains And Losses For The Securities Held) (Detail) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | $ 1,549 | $ 1,554 |
Gross Unrealized Gains | 192 | 238 |
Gross Unrealized Losses | (26) | (12) |
Fair Value | 1,715 | 1,780 |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | Equity Securities [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 667 | 685 |
Gross Unrealized Gains | 176 | 220 |
Gross Unrealized Losses | (18) | (8) |
Fair Value | 825 | 897 |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | Government Obligations [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 445 | 430 |
Gross Unrealized Gains | 10 | 9 |
Gross Unrealized Losses | (1) | (1) |
Fair Value | 454 | 438 |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | Other Debt Securities [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 402 | 333 |
Gross Unrealized Gains | 6 | 9 |
Gross Unrealized Losses | (7) | (3) |
Fair Value | 401 | 339 |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | Total Debt Securities [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 847 | 763 |
Gross Unrealized Gains | 16 | 18 |
Gross Unrealized Losses | (8) | (4) |
Fair Value | 855 | 777 |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | Other Securities [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 35 | 106 |
Gross Unrealized Gains | 0 | 0 |
Gross Unrealized Losses | 0 | 0 |
Fair Value | 35 | 106 |
Rabbi Trust [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 204 | 177 |
Gross Unrealized Gains | 10 | 14 |
Gross Unrealized Losses | (3) | 0 |
Fair Value | 211 | 191 |
Rabbi Trust [Member] | Equity Securities [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 11 | 12 |
Gross Unrealized Gains | 9 | 11 |
Gross Unrealized Losses | 0 | 0 |
Fair Value | 20 | 23 |
Rabbi Trust [Member] | Government Obligations [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 106 | 89 |
Gross Unrealized Gains | 1 | 2 |
Gross Unrealized Losses | (1) | 0 |
Fair Value | 106 | 91 |
Rabbi Trust [Member] | Other Debt Securities [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 86 | 74 |
Gross Unrealized Gains | 0 | 1 |
Gross Unrealized Losses | (2) | 0 |
Fair Value | 84 | 75 |
Rabbi Trust [Member] | Total Debt Securities [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 192 | 163 |
Gross Unrealized Gains | 1 | 3 |
Gross Unrealized Losses | (3) | 0 |
Fair Value | 190 | 166 |
Rabbi Trust [Member] | Other Securities [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Cost | 1 | 2 |
Gross Unrealized Gains | 0 | 0 |
Gross Unrealized Losses | 0 | 0 |
Fair Value | 1 | 2 |
Rabbi Trust [Member] | Power [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Fair Value | $ 52 | $ 45 |
Available-For-Sale Securities49
Available-For-Sale Securities (Schedule Of Accounts Receivable And Accounts Payable) (Detail) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Accounts Receivable | $ 10 | $ 10 |
Accounts Payable | 4 | 2 |
Rabbi Trust [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Accounts Receivable | 1 | 1 |
Accounts Payable | $ 1 | $ 0 |
Available-For-Sale Securities50
Available-For-Sale Securities (Value Of Securities That Have Been In An Unrealized Loss Position For Less Than And Greater Than 12 Months) (Detail) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 | |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | |||
Schedule of Available-for-sale Securities [Line Items] | |||
Continuous Unrealized Loss Position, Less Than 12 Months, Fair Value | $ 397 | $ 356 | |
Continuous Unrealized Loss Position, Less Than 12 Months, Gross Unrealized Losses | (24) | (9) | |
Continuous Unrealized Loss Position, Greater Than 12 Months, Fair Value | 45 | 59 | |
Continuous Unrealized Loss Position, Greater Than 12 Months, Gross Unrealized Losses | (2) | (3) | |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | Equity Securities [Member] | |||
Schedule of Available-for-sale Securities [Line Items] | |||
Continuous Unrealized Loss Position, Less Than 12 Months, Fair Value | [1] | 143 | 162 |
Continuous Unrealized Loss Position, Less Than 12 Months, Gross Unrealized Losses | [1] | (18) | (8) |
Continuous Unrealized Loss Position, Greater Than 12 Months, Fair Value | [1] | 1 | 1 |
Continuous Unrealized Loss Position, Greater Than 12 Months, Gross Unrealized Losses | [1] | 0 | 0 |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | Government Obligations [Member] | |||
Schedule of Available-for-sale Securities [Line Items] | |||
Continuous Unrealized Loss Position, Less Than 12 Months, Fair Value | [2] | 90 | 95 |
Continuous Unrealized Loss Position, Less Than 12 Months, Gross Unrealized Losses | [2] | (1) | 0 |
Continuous Unrealized Loss Position, Greater Than 12 Months, Fair Value | [2] | 15 | 28 |
Continuous Unrealized Loss Position, Greater Than 12 Months, Gross Unrealized Losses | [2] | 0 | (1) |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | Other Debt Securities [Member] | |||
Schedule of Available-for-sale Securities [Line Items] | |||
Continuous Unrealized Loss Position, Less Than 12 Months, Fair Value | [3] | 164 | 99 |
Continuous Unrealized Loss Position, Less Than 12 Months, Gross Unrealized Losses | [3] | (5) | (1) |
Continuous Unrealized Loss Position, Greater Than 12 Months, Fair Value | [3] | 29 | 30 |
Continuous Unrealized Loss Position, Greater Than 12 Months, Gross Unrealized Losses | [3] | (2) | (2) |
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | Total Debt Securities [Member] | |||
Schedule of Available-for-sale Securities [Line Items] | |||
Continuous Unrealized Loss Position, Less Than 12 Months, Fair Value | 254 | 194 | |
Continuous Unrealized Loss Position, Less Than 12 Months, Gross Unrealized Losses | (6) | (1) | |
Continuous Unrealized Loss Position, Greater Than 12 Months, Fair Value | 44 | 58 | |
Continuous Unrealized Loss Position, Greater Than 12 Months, Gross Unrealized Losses | (2) | (3) | |
Rabbi Trust [Member] | |||
Schedule of Available-for-sale Securities [Line Items] | |||
Continuous Unrealized Loss Position, Less Than 12 Months, Fair Value | 88 | 26 | |
Continuous Unrealized Loss Position, Less Than 12 Months, Gross Unrealized Losses | (3) | 0 | |
Continuous Unrealized Loss Position, Greater Than 12 Months, Fair Value | 11 | 0 | |
Continuous Unrealized Loss Position, Greater Than 12 Months, Gross Unrealized Losses | 0 | 0 | |
Rabbi Trust [Member] | Equity Securities [Member] | |||
Schedule of Available-for-sale Securities [Line Items] | |||
Continuous Unrealized Loss Position, Less Than 12 Months, Fair Value | [4] | 0 | 0 |
Continuous Unrealized Loss Position, Less Than 12 Months, Gross Unrealized Losses | [4] | 0 | 0 |
Continuous Unrealized Loss Position, Greater Than 12 Months, Fair Value | [4] | 0 | 0 |
Continuous Unrealized Loss Position, Greater Than 12 Months, Gross Unrealized Losses | [4] | 0 | 0 |
Rabbi Trust [Member] | Government Obligations [Member] | |||
Schedule of Available-for-sale Securities [Line Items] | |||
Continuous Unrealized Loss Position, Less Than 12 Months, Fair Value | [5] | 47 | 2 |
Continuous Unrealized Loss Position, Less Than 12 Months, Gross Unrealized Losses | [5] | (2) | 0 |
Continuous Unrealized Loss Position, Greater Than 12 Months, Fair Value | [5] | 2 | 0 |
Continuous Unrealized Loss Position, Greater Than 12 Months, Gross Unrealized Losses | [5] | 0 | 0 |
Rabbi Trust [Member] | Other Debt Securities [Member] | |||
Schedule of Available-for-sale Securities [Line Items] | |||
Continuous Unrealized Loss Position, Less Than 12 Months, Fair Value | [6] | 41 | 24 |
Continuous Unrealized Loss Position, Less Than 12 Months, Gross Unrealized Losses | [6] | (1) | 0 |
Continuous Unrealized Loss Position, Greater Than 12 Months, Fair Value | [6] | 9 | 0 |
Continuous Unrealized Loss Position, Greater Than 12 Months, Gross Unrealized Losses | [6] | 0 | 0 |
Rabbi Trust [Member] | Total Debt Securities [Member] | |||
Schedule of Available-for-sale Securities [Line Items] | |||
Continuous Unrealized Loss Position, Less Than 12 Months, Fair Value | 88 | 26 | |
Continuous Unrealized Loss Position, Less Than 12 Months, Gross Unrealized Losses | (3) | 0 | |
Continuous Unrealized Loss Position, Greater Than 12 Months, Fair Value | 11 | 0 | |
Continuous Unrealized Loss Position, Greater Than 12 Months, Gross Unrealized Losses | $ 0 | $ 0 | |
[1] | Equity Securities—Investments in marketable equity securities within the NDT Fund are primarily in common stocks within a broad range of industries and sectors. The unrealized losses are distributed over a broad range of securities with limited impairment durations. Power does not consider these securities to be other-than-temporarily impaired as of September 30, 2015. | ||
[2] | Debt Securities (Government)—Unrealized losses on Power’s NDT investments in United States Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. Since these investments are guaranteed by the United States government or an agency of the United States government, it is not expected that these securities will settle for less than their amortized cost basis, since Power does not intend to sell nor will it be more-likely-than-not required to sell. Power does not consider these securities to be other-than-temporarily impaired as of September 30, 2015. | ||
[3] | Debt Securities (Other)—Power’s investments in corporate bonds, collateralized mortgage obligations, asset-backed securities and municipal government obligations are limited to investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since Power does not intend to sell these securities nor will it be more-likely-than-not required to sell, Power does not consider these debt securities to be other-than-temporarily impaired as of September 30, 2015. | ||
[4] | Equity Securities—Investments in marketable equity securities within the Rabbi Trust Fund are through a mutual fund which invests primarily in common stocks within a broad range of industries and sectors. | ||
[5] | Debt Securities (Government)—Unrealized losses on PSEG’s Rabbi Trust investments in United States Treasury obligations and Federal Agency mortgage-backed securities were caused by interest rate changes. Since these investments are guaranteed by the United States government or an agency of the United States government, it is not expected that these securities will settle for less than their amortized cost basis, since PSEG does not intend to sell nor will it be more-likely-than-not required to sell. PSEG does not consider these securities to be other-than-temporarily impaired as of September 30, 2015. | ||
[6] | Debt Securities (Other)—PSEG’s investments in corporate bonds, collateralized mortgage obligations, asset-backed securities and municipal government obligations are limited to investment grade securities. It is not expected that these securities would settle for less than their amortized cost. Since PSEG does not intend to sell these securities nor will it be more-likely-than-not required to sell, PSEG does not consider these debt securities to be other-than-temporarily impaired as of September 30, 2015. |
Available-For-Sale Securities51
Available-For-Sale Securities (Proceeds From The Sales Of And The Net Realized Gains On Securities in the NDT and Rabbi Trusts) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | ||
Rabbi Trust [Member] | |||||
Schedule of Available-for-sale Securities [Line Items] | |||||
Proceeds from Sales | [1] | $ 20 | $ 419 | $ 83 | $ 445 |
Gross Realized Gains | 0 | 2 | 2 | 4 | |
Gross Realized Losses | (1) | (2) | (1) | (3) | |
Net Realized Gains (Losses) | (1) | 0 | 1 | 1 | |
Power [Member] | Nuclear Decommissioning Trust (NDT) Fund [Member] | |||||
Schedule of Available-for-sale Securities [Line Items] | |||||
Proceeds from Sales | [2] | 215 | 221 | 1,037 | 779 |
Gross Realized Gains | 14 | 45 | 47 | 101 | |
Gross Realized Losses | (11) | (3) | (24) | (12) | |
Net Realized Gains (Losses) | $ 3 | $ 42 | $ 23 | $ 89 | |
[1] | Includes activity in accounts related to the liquidation of funds being transitioned to new managers | ||||
[2] | Includes activity in accounts related to the liquidation of funds being transitioned to new managers |
Available-For-Sale Securities52
Available-For-Sale Securities (Amount Of Available-For-Sale Debt Securities By Maturity Periods) (Detail) $ in Millions | Sep. 30, 2015USD ($) |
Rabbi Trust [Member] | |
Schedule of Available-for-sale Securities [Line Items] | |
Less than one year | $ 5 |
1 - 5 years | 49 |
6 - 10 years | 39 |
11 - 15 years | 8 |
16 - 20 years | 9 |
Over 20 years | 80 |
Total Available-for-Sale Debt Securities | 190 |
Power [Member] | Nuclear Decommissioning Trust (NDT) Fund [Member] | |
Schedule of Available-for-sale Securities [Line Items] | |
Less than one year | 8 |
1 - 5 years | 236 |
6 - 10 years | 201 |
11 - 15 years | 51 |
16 - 20 years | 51 |
Over 20 years | 308 |
Total Available-for-Sale Debt Securities | $ 855 |
Available-For-Sale Securities53
Available-For-Sale Securities (Fair Value Of Rabbi Trust) (Detail) - Rabbi Trust [Member] - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Schedule of Available-for-sale Securities [Line Items] | ||
Total Rabbi Trust Available-for-Sale Securities | $ 211 | $ 191 |
Power [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Total Rabbi Trust Available-for-Sale Securities | 52 | 45 |
PSE And G [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Total Rabbi Trust Available-for-Sale Securities | 42 | 41 |
Other Entity [Member] | ||
Schedule of Available-for-sale Securities [Line Items] | ||
Total Rabbi Trust Available-for-Sale Securities | $ 117 | $ 105 |
Available-For-Sale Securities54
Available-For-Sale Securities (Narrative) (Detail) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015USD ($) | Sep. 30, 2014USD ($) | Sep. 30, 2015USD ($)Facility | Sep. 30, 2014USD ($) | |
Schedule of Available-for-sale Securities [Line Items] | ||||
Other-Than Temporary Impairments | $ 30 | $ 10 | $ 45 | $ 14 |
Power [Member] | ||||
Schedule of Available-for-sale Securities [Line Items] | ||||
Number of Nuclear Facilities | Facility | 5 | |||
Other-Than Temporary Impairments | $ 30 | $ 10 | $ 45 | $ 14 |
Nuclear Decommissioning Trust (NDT) Fund [Member] | ||||
Schedule of Available-for-sale Securities [Line Items] | ||||
Other-Than Temporary Impairments | 45 | |||
Nuclear Decommissioning Trust (NDT) Fund [Member] | Power [Member] | ||||
Schedule of Available-for-sale Securities [Line Items] | ||||
After tax amount of net unrealized gains recognized in AOCI | 82 | |||
Rabbi Trust [Member] | Debt Securities [Member] | ||||
Schedule of Available-for-sale Securities [Line Items] | ||||
After tax amount of net unrealized gains recognized in AOCI | $ 4 |
Pension And OPEB (Components Of
Pension And OPEB (Components Of Net Periodic Benefit Cost) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Pension Benefits [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service Cost | $ 30 | $ 26 | $ 92 | $ 78 |
Interest Cost | 59 | 58 | 176 | 176 |
Expected Return on Plan Assets | (103) | (99) | (310) | (299) |
Amortization of Prior Service Cost | (5) | (5) | (14) | (14) |
Amortization of Actuarial Loss | 38 | 14 | 112 | 42 |
Total Benefit Costs | 19 | (6) | 56 | (17) |
OPEB [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Service Cost | 5 | 5 | 16 | 14 |
Interest Cost | 16 | 18 | 50 | 52 |
Expected Return on Plan Assets | (7) | (7) | (22) | (20) |
Amortization of Prior Service Cost | (4) | (4) | (11) | (11) |
Amortization of Actuarial Loss | 11 | 6 | 32 | 18 |
Total Benefit Costs | $ 21 | $ 18 | $ 65 | $ 53 |
Pension And OPEB (Schedule Of P
Pension And OPEB (Schedule Of Pension And OPEB Costs) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Pension Benefits [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Total Benefit Costs | $ 19 | $ (6) | $ 56 | $ (17) |
Pension Benefits [Member] | PSE And G [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Total Benefit Costs | 10 | (4) | 30 | (14) |
Pension Benefits [Member] | Power [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Total Benefit Costs | 5 | (2) | 16 | (5) |
Pension Benefits [Member] | Other Entity [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Total Benefit Costs | 4 | 0 | 10 | 2 |
OPEB [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Total Benefit Costs | 21 | 18 | 65 | 53 |
OPEB [Member] | PSE And G [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Total Benefit Costs | 13 | 12 | 41 | 35 |
OPEB [Member] | Power [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Total Benefit Costs | 7 | 5 | 20 | 15 |
OPEB [Member] | Other Entity [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Total Benefit Costs | $ 1 | $ 1 | $ 4 | $ 3 |
Pension And OPEB (Narrative) (D
Pension And OPEB (Narrative) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Pension Plan [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Employer contributions | $ 15 | |||
Total Benefit Costs | $ 19 | $ (6) | 56 | $ (17) |
Postretirement Healthcare Plans [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Employer contributions | 14 | |||
Total Benefit Costs | 21 | 18 | 65 | 53 |
Long Island Electric Utility Servco LLC Pension and OPEB [Member] | ||||
Defined Benefit Plan Disclosure [Line Items] | ||||
Total Benefit Costs | $ 17 | $ 21 | $ 30 | $ 67 |
Commitments And Contingent Li58
Commitments And Contingent Liabilities (Guaranteed Obligations) (Detail) - Power [Member] - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Loss Contingencies [Line Items] | ||
Face Value of Outstanding Guarantees | $ 1,733 | $ 1,814 |
Exposure under Current Guarantees | 184 | 273 |
Letters of Credit Margin Posted | 178 | 159 |
Letters of Credit Margin Received | 80 | 40 |
Counterparty Cash Margin Deposited | 0 | 0 |
Counterparty Cash Margin Received | (44) | (13) |
Net Broker Balance Deposited (Received) | 4 | 115 |
Additional Collateral that could be Required | 796 | 945 |
Liquidity Available under PSEG’s and Power’s Credit Facilities to Post Collateral | 3,375 | 3,495 |
Other Letters of Credit | 47 | $ 45 |
PennEast Natural Gas Pipeline [Member] | ||
Loss Contingencies [Line Items] | ||
Face Value of Outstanding Guarantees | 106 | |
755 MW Gas-Fired Combined Cycle Generating Station [Member] | ||
Loss Contingencies [Line Items] | ||
Face Value of Outstanding Guarantees | $ 21 |
Commitments And Contingent Li59
Commitments And Contingent Liabilities (Environmental Matters) (Detail) | 1 Months Ended | 9 Months Ended | ||||
Jun. 30, 2008USD ($) | Sep. 30, 2015USD ($)Potentially_Responsible_PartysiteentityStationPlantmi | Dec. 31, 2014USD ($) | Mar. 31, 2007Potentially_Responsible_Party | Dec. 31, 2006 | Dec. 31, 2003Potentially_Responsible_Party | |
Site Contingency [Line Items] | ||||||
Number of miles related to the Passaic River constituting a facility as determined by the US Environmental Protection Agency | mi | 17 | |||||
Number of miles on Passaic River tidal reach required to be studied as determined by the US Environmental Protection Agency | mi | 8 | |||||
Number of additional legal entities contacted by EPA in conjunction with Newark Bay study area contamination | entity | 11 | |||||
Number of operating electric generating stations located on Hackensack River | Station | 2 | |||||
Number of former MGP contamination sites located on Hackensack river in conjunction with Newark Bay study area contamination | site | 1 | |||||
Accrued environmental costs | $ 438,000,000 | $ 417,000,000 | ||||
New Salem facility cooling towers estimated cost total | 1,000,000,000 | |||||
PSE And G [Member] | ||||||
Site Contingency [Line Items] | ||||||
Percentage of cost attributable to potentially responsible party | 7.00% | |||||
Accrued environmental costs | $ 387,000,000 | $ 364,000,000 | ||||
Power [Member] | ||||||
Site Contingency [Line Items] | ||||||
Ownership percentage of Keystone Coal fired plant in Pennsylvania | 23.00% | |||||
New Salem facility cooling towers estimated cost total | $ 575,000,000 | |||||
Psd Nsr Regulations Site Contingency [Member] | Power [Member] | ||||||
Site Contingency [Line Items] | ||||||
Penalty per day from date of violation-minimum | 25,000 | |||||
Penalty per day from date of violation-maximum | $ 37,500 | |||||
Pse G S Former Mgp Sites [Member] | ||||||
Site Contingency [Line Items] | ||||||
Number of potentially responsible parties ("PRPs") in connection with environmental liabilities for operations conducted near Passaic River | Potentially_Responsible_Party | 60 | 73 | ||||
Estimated, total cost of the study | $ 151,000,000 | |||||
Total Spend of Study to date | 141,000,000 | |||||
Company Share of Total Spend of Study to date | $ 9,000,000 | |||||
Number of MGP sites identified by registrant and the NJDEP requiring some level of remedial action | site | 38 | |||||
Pse G S Former Mgp Sites [Member] | Power [Member] | ||||||
Site Contingency [Line Items] | ||||||
Percentage of cost attributable to potentially responsible party | 1.00% | |||||
Passaic River Site Contingency [Member] | ||||||
Site Contingency [Line Items] | ||||||
Estimated cleanup costs-low estimate | $ 365,000,000 | |||||
Estimated cleanup costs-high estimate | 3,250,000,000 | |||||
Estimated Cleanup Costs EPA Preferred Method | 1,700,000,000 | |||||
CPG Estimated Cleanup Costs Low Estimate | 518,000,000 | |||||
CPG Estimated Cleanup Costs High Estimate | 3,200,000,000 | |||||
CPG Targeted Method Cleanup Costs Low Estimate | 518,000,000 | |||||
Number Of Additional Potentially Responsible Parties Directed By New Jersey Department Of Environmental Protection To Arrange Damage Assessment For Lower Passaic River | Potentially_Responsible_Party | 56 | |||||
CPG Targeted Remedy Cleanup Costs High Estimate | 772,000,000 | |||||
Estimated cleanup costs agreed to by two potentially responsible parties | $ 80,000,000 | |||||
Estimated cost of interim natural resource injury restoration | $ 950,000,000 | |||||
Passaic River Site Contingency [Member] | PSE And G [Member] | ||||||
Site Contingency [Line Items] | ||||||
Number of former generating electric station | Plant | 1 | |||||
Number of former Manufactured Gas Plant (MGP) sites | Plant | 4 | |||||
CPG Targeted Method Cleanup Costs Low Estimate | $ 10,000,000 | |||||
Passaic River Site Contingency [Member] | Power [Member] | ||||||
Site Contingency [Line Items] | ||||||
CPG Targeted Method Cleanup Costs Low Estimate | 3,000,000 | |||||
Remedial Investigation And Feasibility Study [Member] | ||||||
Site Contingency [Line Items] | ||||||
Estimated, total cost of the study | 30,000,000 | |||||
Estimated Total Cost Of Study Low End of Range | 25,000,000 | |||||
MGP Remediation Site Contingency [Member] | PSE And G [Member] | ||||||
Site Contingency [Line Items] | ||||||
Estimated expenditures, low end of range | 450,000,000 | |||||
Estimated expenditures, high end of range | 518,000,000 | |||||
Accrued environmental costs | 450,000,000 | |||||
Remediation liability recorded as other current liabilities | 73,000,000 | |||||
Remediation liability recorded as environmental costs in noncurrent liabilities | 377,000,000 | |||||
Regulatory assets | $ 450,000,000 | |||||
Passaic River mile 10.9 contaminant removal [Member] | ||||||
Site Contingency [Line Items] | ||||||
Percentage of cost attributable to potentially responsible party | 3.00% |
Commitments And Contingent Li60
Commitments And Contingent Liabilities (Basic Generation Service (BGS) And Basic Gas Supply Service (BGSS)) (Detail) cf in Billions | 9 Months Ended | |
Sep. 30, 2015cf$ / mwh$ / mwdMW | ||
Long-term Purchase Commitment [Line Items] | ||
Number of cubic feet in gas hedging permitted to be recovered by BPU | cf | 115 | |
Percentage of residential gas supply permitted to be recovered in gas hedging by BPU | 80.00% | |
Number of cubic feet to be hedged | cf | 70 | |
Percentage of annual residential gas supply requirements to be hedged | 50.00% | |
PSE And G [Member] | Auction Year 2012 [Member] | ||
Long-term Purchase Commitment [Line Items] | ||
36-Month Terms Ending | May 31, 2015 | |
Load (MW) | MW | 2,900 | |
Dollars Per Megawatt Hour | 83.88 | |
PSE And G [Member] | Auction Year 2013 [Member] | ||
Long-term Purchase Commitment [Line Items] | ||
36-Month Terms Ending | May 31, 2016 | |
Load (MW) | MW | 2,800 | |
Dollars Per Megawatt Hour | 92.18 | |
PSE And G [Member] | Auction Year 2014 [Member] | ||
Long-term Purchase Commitment [Line Items] | ||
Dollars Per Megawatt-Day | $ / mwd | 282.04 | |
36-Month Terms Ending | May 31, 2017 | |
Load (MW) | MW | 2,800 | |
Dollars Per Megawatt Hour | 97.39 | |
PSE And G [Member] | Auction Year 2015 [Member] | ||
Long-term Purchase Commitment [Line Items] | ||
Dollars Per Megawatt-Day | $ / mwd | 272.78 | |
36-Month Terms Ending | May 31, 2018 | [1] |
Load (MW) | MW | 2,900 | |
Dollars Per Megawatt Hour | 99.54 | |
[1] | Prices set for the 2015 BGS auction year became effective on June 1, 2015 when the 2012 BGS auction agreements expired. |
Commitments And Contingent Li61
Commitments And Contingent Liabilities (Minimum Fuel Purchase Requirements) (Detail) - Power [Member] $ in Millions | 9 Months Ended |
Sep. 30, 2015USD ($) | |
Long-term Purchase Commitment [Line Items] | |
Coverage percentage of nuclear fuel commitments of uranium, enrichment, and fabrication requirements | 100.00% |
Commitments Through 2019 [Member] | Nuclear Fuel Uranium [Member] | |
Long-term Purchase Commitment [Line Items] | |
Total minimum purchase requirements | $ 440 |
Commitments Through 2019 [Member] | Nuclear Fuel Enrichment [Member] | |
Long-term Purchase Commitment [Line Items] | |
Total minimum purchase requirements | 345 |
Commitments Through 2019 [Member] | Nuclear Fuel Fabrication [Member] | |
Long-term Purchase Commitment [Line Items] | |
Total minimum purchase requirements | 179 |
Commitments Through 2019 [Member] | Natural Gas [Member] | |
Long-term Purchase Commitment [Line Items] | |
Total minimum purchase requirements | 1,001 |
Commitments Through 2019 [Member] | Coal [Member] | |
Long-term Purchase Commitment [Line Items] | |
Total minimum purchase requirements | $ 331 |
Commitments And Contingent Li62
Commitments And Contingent Liabilities (Regulatory Proceedings and Superstorm Sandy) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | 30 Months Ended | 39 Months Ended | ||||||
Sep. 30, 2015 | Jun. 30, 2015 | Mar. 31, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | Dec. 31, 2013 | Dec. 31, 2012 | Jun. 30, 2015 | Mar. 31, 2015 | Dec. 31, 2014 | |
Loss Contingencies [Line Items] | |||||||||||
Clean Energy Program, current portion | $ 185 | $ 185 | $ 142 | ||||||||
Operation and Maintenance | 746 | $ 714 | 2,170 | $ 2,370 | |||||||
Insurance Recovery | 28 | ||||||||||
New Jersey Clean Energy Program Regulatory Action [Member] | |||||||||||
Loss Contingencies [Line Items] | |||||||||||
Aggregate funding level for fiscal year 2016 for New Jersey Clean Energy Program | 345 | 345 | |||||||||
Superstorm Sandy [Member] | |||||||||||
Loss Contingencies [Line Items] | |||||||||||
Proceeds from Insurance Recoveries | $ 55 | $ 159 | 214 | $ 264 | |||||||
PSE And G [Member] | |||||||||||
Loss Contingencies [Line Items] | |||||||||||
Clean Energy Program, current portion | 185 | 185 | $ 142 | ||||||||
Operation and Maintenance | 391 | 366 | 1,171 | 1,190 | |||||||
Insurance Recovery | 0 | ||||||||||
PSE And G [Member] | New Jersey Clean Energy Program Regulatory Action [Member] | |||||||||||
Loss Contingencies [Line Items] | |||||||||||
Aggregate funding level for fiscal year 2016 for New Jersey Clean Energy Program | 200 | 200 | |||||||||
Clean Energy Program, current portion | 185 | 185 | |||||||||
PSE And G [Member] | Superstorm Sandy [Member] | |||||||||||
Loss Contingencies [Line Items] | |||||||||||
Utilities, Costs Incurred to Repair Infrastructure to Pre-Storm Conditions | $ 5 | ||||||||||
Utilities, Costs Incurred to Restore Service portion attributable to insured property | 36 | ||||||||||
Utilities, Costs Incurred to Restore Service | 295 | ||||||||||
Operation and Maintenance | (10) | 40 | |||||||||
Proceeds from Insurance Recoveries | 35 | 6 | |||||||||
Public Utilities, Property, Plant and Equipment, Addition from Service Restore | 11 | (75) | |||||||||
Regulatory Assets, Addition for Service Restore | 20 | $ (180) | |||||||||
Power [Member] | |||||||||||
Loss Contingencies [Line Items] | |||||||||||
Operation and Maintenance | $ 263 | $ 242 | 748 | 871 | |||||||
Insurance Recovery | 28 | ||||||||||
Power [Member] | FERC Compliance [Domain] | |||||||||||
Loss Contingencies [Line Items] | |||||||||||
Loss Contingency related to bidding errors | $ 25 | ||||||||||
Power [Member] | Superstorm Sandy [Member] | |||||||||||
Loss Contingencies [Line Items] | |||||||||||
Operation and Maintenance | 2 | $ 193 | |||||||||
Proceeds from Insurance Recoveries | 179 | $ 44 | |||||||||
Insurance Recovery | 145 | ||||||||||
Property, Plant and Equipment [Member] | Power [Member] | Superstorm Sandy [Member] | |||||||||||
Loss Contingencies [Line Items] | |||||||||||
Insurance Recovery | 6 | ||||||||||
Other Income [Member] | |||||||||||
Loss Contingencies [Line Items] | |||||||||||
Insurance Recovery | $ 28 |
Changes In Capitalization (Deta
Changes In Capitalization (Detail) | 9 Months Ended |
Sep. 30, 2015USD ($) | |
Power [Member] | |
Debt Instrument [Line Items] | |
Cash dividends paid to parent company | $ 400,000,000 |
Medium Term Notes Three Point Zero Percent Due In Two Thousand Twenty Five [Member] | PSE And G [Member] | |
Debt Instrument [Line Items] | |
Issued long-term debt | $ 350,000,000 |
Stated interest rate of debt instrument | 3.00% |
Medium Term Notes Four Point Zero Five Percent due Two Thousand Forty Five [Member] | PSE And G [Member] | |
Debt Instrument [Line Items] | |
Issued long-term debt | $ 250,000,000 |
Stated interest rate of debt instrument | 4.05% |
Medium Term Notes Two Point Seven Zero Percentage Due On Two Thousand Fifteen [Member] | PSE And G [Member] | |
Debt Instrument [Line Items] | |
Stated interest rate of debt instrument | 2.70% |
Repayments of long-term debt | $ 300,000,000 |
Securitization Debt [Member] | PSE And G [Member] | |
Debt Instrument [Line Items] | |
Repayments of long-term debt | 183,000,000 |
Transition Fundings Ii Securitization Debt [Member] | PSE And G [Member] | |
Debt Instrument [Line Items] | |
Repayments of long-term debt | $ 8,000,000 |
Financial Risk Management Act64
Financial Risk Management Activities (Schedule Of Derivative Transactions Designated And Effective As Cash Flow Hedges) (Detail) - Power [Member] - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | ||
Fair Value of Cash Flow Hedges | $ 2 | $ 18 |
Impact on Accumulated Other Comprehensive Income (Loss) (after tax) | $ 1 | $ 10 |
Financial Risk Management Act65
Financial Risk Management Activities (Narrative) (Detail) $ in Millions | 9 Months Ended | ||
Sep. 30, 2015USD ($)Counterparty | Sep. 30, 2014USD ($) | Dec. 31, 2014USD ($) | |
Derivatives, Fair Value [Line Items] | |||
Net cash collateral received in connection with net derivative contracts | $ (58) | $ 24 | |
Aggregate fair value of derivative contracts in a liability position that contains triggers for additional collateral | 78 | 127 | |
Additional collateral aggregate fair value | 796 | 945 | |
Power [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Net exposure | 246 | ||
Amount of after-tax gains on derivatives designated and effective as cash flow hedges expected to be reclassified to earnings during the 12 months following period end | $ 1 | ||
Credit exposure, percentage | 98.00% | ||
Number of active counterparties on credit risk derivatives | Counterparty | 133 | ||
Power [Member] | Senior Notes 5.32% Due September 2016 [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Senior Notes converted into variable rate debt | $ 303 | ||
PSEG [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Aggregate amount of series of interest rate swaps converting to variable-rate debt | 850 | ||
Fair value of interest rate swaps designated as underlying hedges | 11 | 22 | |
Aggregate fair value of derivative contracts in a liability position that contains triggers for additional collateral | 12 | ||
Additional collateral aggregate fair value | 66 | 109 | |
Amount of reduction in interest expense attributed to interest rate swaps designated as fair value hedges | (5) | $ (15) | |
PSEG [Member] | Senior Notes 5.5% Due December 2015 [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Senior Notes converted into variable rate debt | $ 300 | ||
Stated interest rate of debt instrument | 5.50% | ||
PSEG [Member] | Senior Notes 5.32% Due September 2016 [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Senior Notes converted into variable rate debt | $ 300 | ||
Stated interest rate of debt instrument | 5.32% | ||
PSEG [Member] | Senior Notes 2.75% Due September 2016 [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Senior Notes converted into variable rate debt | $ 250 | ||
Stated interest rate of debt instrument | 2.75% | ||
Non Current Assets [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Net cash collateral received in connection with net derivative contracts | $ (38) | $ (8) | |
Investment Grade - External Rating [Member] | Power [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Net exposure | 230 | ||
Investment Grade - External Rating [Member] | PSE And G [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Net exposure | 87 | ||
Investment Grade - External Rating [Member] | Nonaffiliated [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Net exposure | $ 40 |
Financial Risk Management Act66
Financial Risk Management Activities (Schedule Of Derivative Instruments Fair Value In Balance Sheets) (Detail) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 | |
Derivatives, Fair Value [Line Items] | |||
Derivative Contracts, Current Assets | $ 162 | $ 240 | |
Derivative Contracts, Noncurrent Assets | 91 | 77 | |
Total Mark-to-Market Derivative Assets | 253 | 317 | |
Derivative Contracts, Current Liabilities | (70) | (132) | |
Derivative Contracts, Noncurrent Liabilities | (23) | (33) | |
Total Mark-to-Market Derivative (Liabilities) | (93) | (165) | |
Net Mark-to-Market Derivative Assets (Liabilities) | 160 | 152 | |
Net cash collateral received in connection with net derivative contracts | (58) | 24 | |
Power [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Derivative Contracts, Current Assets | [1] | 147 | 207 |
Derivative Contracts, Noncurrent Assets | [1] | 91 | 62 |
Total Mark-to-Market Derivative Assets | [1] | 238 | 269 |
Derivative Contracts, Current Liabilities | [1] | (70) | (132) |
Derivative Contracts, Noncurrent Liabilities | [1] | (16) | (33) |
Total Mark-to-Market Derivative (Liabilities) | [1] | (86) | (165) |
Net Mark-to-Market Derivative Assets (Liabilities) | [1] | 152 | 104 |
Power [Member] | Netting [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Derivative Contracts, Current Assets | [1],[2] | (268) | (408) |
Derivative Contracts, Noncurrent Assets | [1],[2] | (193) | (109) |
Total Mark-to-Market Derivative Assets | [1],[2] | (461) | (517) |
Derivative Contracts, Current Liabilities | [1],[2] | 241 | 436 |
Derivative Contracts, Noncurrent Liabilities | [1],[2] | 162 | 105 |
Total Mark-to-Market Derivative (Liabilities) | [1],[2] | 403 | 541 |
Net Mark-to-Market Derivative Assets (Liabilities) | [1],[2] | (58) | 24 |
Power [Member] | Energy-Related Contracts [Member] | Cash Flow Hedging [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Derivative Contracts, Current Assets | [1] | 2 | 18 |
Derivative Contracts, Noncurrent Assets | [1] | 0 | 0 |
Total Mark-to-Market Derivative Assets | [1] | 2 | 18 |
Derivative Contracts, Current Liabilities | [1] | 0 | 0 |
Derivative Contracts, Noncurrent Liabilities | [1] | 0 | 0 |
Total Mark-to-Market Derivative (Liabilities) | [1] | 0 | 0 |
Net Mark-to-Market Derivative Assets (Liabilities) | [1] | 2 | 18 |
PSE And G [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Derivative Contracts, Current Assets | 4 | 18 | |
Derivative Contracts, Noncurrent Assets | 0 | 8 | |
Derivative Contracts, Noncurrent Liabilities | (7) | 0 | |
PSEG [Member] | Interest Rate Swap [Member] | Fair Value Hedging [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Derivative Contracts, Current Assets | [1] | 11 | 15 |
Derivative Contracts, Noncurrent Assets | [1] | 0 | 7 |
Total Mark-to-Market Derivative Assets | [1] | 11 | 22 |
Derivative Contracts, Current Liabilities | [1] | 0 | 0 |
Derivative Contracts, Noncurrent Liabilities | [1] | 0 | 0 |
Total Mark-to-Market Derivative (Liabilities) | [1] | 0 | 0 |
Net Mark-to-Market Derivative Assets (Liabilities) | [1] | 11 | 22 |
Not Designated as Hedging Instrument [Member] | Power [Member] | Energy-Related Contracts [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Derivative Contracts, Current Assets | [1] | 413 | 597 |
Derivative Contracts, Noncurrent Assets | [1] | 284 | 171 |
Total Mark-to-Market Derivative Assets | [1] | 697 | 768 |
Derivative Contracts, Current Liabilities | [1] | (311) | (568) |
Derivative Contracts, Noncurrent Liabilities | [1] | (178) | (138) |
Total Mark-to-Market Derivative (Liabilities) | [1] | (489) | (706) |
Net Mark-to-Market Derivative Assets (Liabilities) | [1] | 208 | 62 |
Not Designated as Hedging Instrument [Member] | PSE And G [Member] | Energy-Related Contracts [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Derivative Contracts, Current Assets | [1] | 4 | 18 |
Derivative Contracts, Noncurrent Assets | [1] | 0 | 8 |
Total Mark-to-Market Derivative Assets | [1] | 4 | 26 |
Derivative Contracts, Current Liabilities | [1] | 0 | 0 |
Derivative Contracts, Noncurrent Liabilities | [1] | (7) | 0 |
Total Mark-to-Market Derivative (Liabilities) | [1] | (7) | 0 |
Net Mark-to-Market Derivative Assets (Liabilities) | [1] | (3) | 26 |
Current Assets [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Net cash collateral received in connection with net derivative contracts | (32) | (4) | |
Non Current Assets [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Net cash collateral received in connection with net derivative contracts | (38) | (8) | |
Current Liabilities [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Net cash collateral received in connection with net derivative contracts | 5 | 32 | |
Noncurrent Liabilities [Member] | |||
Derivatives, Fair Value [Line Items] | |||
Net cash collateral received in connection with net derivative contracts | $ 7 | $ 4 | |
[1] | Substantially all of Power's and PSEG's derivative instruments are contracts subject to master netting agreements. Contracts not subject to master netting or similar agreements are immaterial and did not have any collateral posted or received as of September 30, 2015 and December 31, 2014. PSE&G does not have any derivative contracts subject to master netting or similar agreements. | ||
[2] | Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral received or posted that has been allocated to derivative positions, where the right of offset exists, has been offset on the Condensed Consolidated Balance Sheets. As of September 30, 2015 and December 31, 2014, net cash collateral (received) paid of $(58) million and $24 million, respectively, were netted against the corresponding net derivative contract positions. Of the $(58) million as of September 30, 2015, $(32) million and $(38) million of cash collateral were netted against current assets and noncurrent assets, respectively, and $5 million and $7 million were netted against current liabilities and noncurrent liabilities, respectively. Of the $24 million as of December 31, 2014, $(4) million and $(8) million were netted against current assets and noncurrent assets, respectively, and $32 million and $4 million were netted against current liabilities and noncurrent liabilities, respectively. |
Financial Risk Management Act67
Financial Risk Management Activities (Schedule Of Derivative Instruments Designated As Cash Flow Hedges) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Interest Expense | $ (96) | $ (100) | $ (291) | $ (291) |
Operating Revenues | 2,688 | 2,641 | 8,137 | 8,113 |
PSEG [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Amount of Pre-Tax Gain (Loss) attributed to Cash Flow Hedges Recognized in AOCI on Derivatives (Effective Portion) | 1 | 3 | 2 | (4) |
Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) | 0 | 0 | 0 | 0 |
Amount of Pre-Tax Gain (Loss) attributed to Cash Flow Hedges Reclassified from AOCI into Energy Costs (Effective Portion) | 0 | 1 | 17 | (11) |
Power [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Amount of Pre-Tax Gain (Loss) attributed to Cash Flow Hedges Recognized in AOCI on Derivatives (Effective Portion) | 1 | 3 | 2 | (4) |
Interest Expense | (30) | (31) | (94) | (92) |
Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) | 0 | 0 | 0 | 0 |
Operating Revenues | 1,096 | 1,138 | 3,846 | 3,824 |
Amount of Pre-Tax Gain (Loss) attributed to Cash Flow Hedges Reclassified from AOCI into Energy Costs (Effective Portion) | 0 | 1 | 17 | (11) |
Operating Revenues [Member] | PSEG [Member] | Energy-Related Contracts [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Amount of Pre-Tax Gain (Loss) attributed to Cash Flow Hedges Recognized in AOCI on Derivatives (Effective Portion) | 1 | 3 | 2 | (4) |
Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) | 0 | 0 | 0 | 0 |
Operating Revenues | 0 | 1 | 17 | (11) |
Operating Revenues [Member] | Power [Member] | Energy-Related Contracts [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Amount of Pre-Tax Gain (Loss) attributed to Cash Flow Hedges Recognized in AOCI on Derivatives (Effective Portion) | 1 | 3 | 2 | (4) |
Amount of Pre-Tax Gain (Loss) Recognized in Income on Derivatives (Ineffective Portion) | $ 0 | 0 | 0 | 0 |
Operating Revenues | $ 1 | $ 17 | $ (11) |
Financial Risk Management Act68
Financial Risk Management Activities (Schedule Of Reconciliation For Derivative Activity Included In Accumulated Other Comprehensive Loss) (Detail) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Jun. 30, 2015 | Sep. 30, 2015 | Sep. 30, 2014 | |
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |||||
Gain (Loss) in AOCI | $ (46) | $ (13) | $ (43) | $ 17 | |
(Gain) Loss into Income | 24 | (13) | 27 | (21) | |
Cash Flow Hedges [Member] | |||||
Derivative Instruments and Hedging Activities Disclosures [Line Items] | |||||
Pre-Tax Balance at Beginning of Period | 1 | $ 17 | 17 | ||
Gain (Loss) in AOCI | 1 | 1 | |||
(Gain) Loss into Income | 0 | (1) | (17) | (17) | 11 |
Pre-Tax Balance at End of Period | 2 | 1 | 2 | ||
After-Tax Balance at Beginning of Period | 1 | 10 | 10 | ||
Gain (Loss) in AOCI | 0 | 2 | 1 | 1 | (2) |
(Gain) Loss into Income | 0 | $ (1) | (10) | (10) | $ 6 |
After-Tax Balance at End of Period | $ 1 | $ 1 | $ 1 |
Financial Risk Management Act69
Financial Risk Management Activities (Schedule Of Derivative Instruments Not Designated As Hedging Instruments And Impact On Results Of Operations) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Pre-Tax Gain (Loss) Recognized in Income on Derivatives | $ 150 | $ 81 | $ 198 | $ (694) |
Operating Revenues [Member] | Energy-Related Contracts [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Pre-Tax Gain (Loss) Recognized in Income on Derivatives | 154 | 93 | 202 | (759) |
Energy Costs [Member] | Energy-Related Contracts [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Pre-Tax Gain (Loss) Recognized in Income on Derivatives | $ (4) | $ (12) | $ (4) | $ 65 |
Financial Risk Management Act70
Financial Risk Management Activities (Schedule Of Gross Volume, On Absolute Basis For Derivative Contracts) (Detail) $ / mwh in Millions, $ / Derivative in Millions, $ / DTH in Millions | 9 Months Ended | 12 Months Ended |
Sep. 30, 2015$ / mwh$ / DTH$ / Derivative | Dec. 31, 2014$ / mwh$ / DTH$ / Derivative | |
Natural Gas Dth [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | $ / DTH | 193 | 274 |
Electricity MWh [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | 291 | 310 |
FTRs MWh [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | 21 | 15 |
Interest Rate Swaps [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | $ / Derivative | 850 | 850 |
PSEG [Member] | Natural Gas Dth [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | 0 | 0 |
PSEG [Member] | Electricity MWh [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | 0 | 0 |
PSEG [Member] | FTRs MWh [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | 0 | 0 |
PSEG [Member] | Interest Rate Swaps [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | $ / Derivative | 850 | 850 |
Power [Member] | Natural Gas Dth [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | $ / DTH | 154 | 216 |
Power [Member] | Electricity MWh [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | 291 | 310 |
Power [Member] | FTRs MWh [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | 21 | 15 |
Power [Member] | Interest Rate Swaps [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | $ / Derivative | 0 | 0 |
PSE And G [Member] | Natural Gas Dth [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | $ / DTH | 39 | 58 |
PSE And G [Member] | Electricity MWh [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | 0 | 0 |
PSE And G [Member] | FTRs MWh [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | 0 | 0 |
PSE And G [Member] | Interest Rate Swaps [Member] | ||
Derivative [Line Items] | ||
Gross Volume of Derivative on Absolute Value Basis | $ / Derivative | 0 | 0 |
Financial Risk Management Act71
Financial Risk Management Activities (Schedule Providing Credit Risk From Others, Net Of Collateral) (Detail) $ in Millions | Sep. 30, 2015USD ($) | |
Power [Member] | ||
Derivative [Line Items] | ||
Current Exposure | $ 364 | |
Securities held as Collateral | 118 | |
Net exposure | 246 | |
Number of Counterparties greater than 10% | 2 | |
Amount Of Net Credit Exposure Greater Than Ten Percent | 127 | |
Power [Member] | Investment Grade - External Rating [Member] | ||
Derivative [Line Items] | ||
Current Exposure | 348 | |
Securities held as Collateral | 118 | |
Net exposure | 230 | |
Number of Counterparties greater than 10% | 2 | |
Amount Of Net Credit Exposure Greater Than Ten Percent | 127 | [1] |
Power [Member] | Non-Investment Grade - External Rating [Member] | ||
Derivative [Line Items] | ||
Current Exposure | 1 | |
Securities held as Collateral | 0 | |
Net exposure | 1 | |
Number of Counterparties greater than 10% | 0 | |
Amount Of Net Credit Exposure Greater Than Ten Percent | 0 | |
Power [Member] | Investment Grade - No External Rating [Member] | ||
Derivative [Line Items] | ||
Current Exposure | 11 | |
Securities held as Collateral | 0 | |
Net exposure | 11 | |
Number of Counterparties greater than 10% | 0 | |
Amount Of Net Credit Exposure Greater Than Ten Percent | 0 | |
Power [Member] | Non-Investment Grade - No External Rating [Member] | ||
Derivative [Line Items] | ||
Current Exposure | 4 | |
Securities held as Collateral | 0 | |
Net exposure | 4 | |
Number of Counterparties greater than 10% | 0 | |
Amount Of Net Credit Exposure Greater Than Ten Percent | 0 | |
PSE And G [Member] | Investment Grade - External Rating [Member] | ||
Derivative [Line Items] | ||
Net exposure | $ 87 | |
[1] | net exposure of $87 million with PSE&G. |
Fair Value Measurements (PSEG's
Fair Value Measurements (PSEG's, Power's And PSE&G's Respective Assets And (Liabilities) Measured At Fair Value On A Recurring Basis) (Detail) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 | ||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | $ 253 | $ 317 | ||
Total Mark-to-Market Derivative (Liabilities) | (93) | (165) | ||
Net cash collateral received in connection with net derivative contracts | (58) | 24 | ||
Power [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [1] | 238 | 269 | |
Total Mark-to-Market Derivative (Liabilities) | [1] | (86) | (165) | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Cash Equivalents, Fair Value Disclosure | [2] | 226 | 365 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Equity Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 824 | 896 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Government Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Other Debt Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 35 | 106 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 20 | 23 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 1 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Power [Member] | Equity Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 824 | 896 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Power [Member] | Government Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Power [Member] | Other Debt Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Power [Member] | Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 35 | 106 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Power [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 5 | 5 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Power [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Power [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | Power [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Cash Equivalents, Fair Value Disclosure | [2] | 0 | 294 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | PSE And G [Member] | Energy-Related Contracts [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative (Liabilities) | 0 | |||
Quoted Market Prices of Identical Assets (Level 1) [Member] | PSE And G [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 4 | 5 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | PSE And G [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | PSE And G [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Quoted Market Prices of Identical Assets (Level 1) [Member] | PSE And G [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Other Observable Inputs (Level 2) [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Cash Equivalents, Fair Value Disclosure | [2] | 0 | 0 | |
Significant Other Observable Inputs (Level 2) [Member] | Equity Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 1 | 1 | |
Significant Other Observable Inputs (Level 2) [Member] | Government Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 454 | 438 | |
Significant Other Observable Inputs (Level 2) [Member] | Other Debt Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 401 | 339 | |
Significant Other Observable Inputs (Level 2) [Member] | Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Other Observable Inputs (Level 2) [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Other Observable Inputs (Level 2) [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 106 | 91 | |
Significant Other Observable Inputs (Level 2) [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 84 | 75 | |
Significant Other Observable Inputs (Level 2) [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 2 | |
Significant Other Observable Inputs (Level 2) [Member] | Power [Member] | Equity Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 1 | 1 | |
Significant Other Observable Inputs (Level 2) [Member] | Power [Member] | Government Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 454 | 438 | |
Significant Other Observable Inputs (Level 2) [Member] | Power [Member] | Other Debt Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 401 | 339 | |
Significant Other Observable Inputs (Level 2) [Member] | Power [Member] | Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Other Observable Inputs (Level 2) [Member] | Power [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Other Observable Inputs (Level 2) [Member] | Power [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 26 | 21 | |
Significant Other Observable Inputs (Level 2) [Member] | Power [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 21 | 18 | |
Significant Other Observable Inputs (Level 2) [Member] | Power [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 1 | |
Significant Other Observable Inputs (Level 2) [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Cash Equivalents, Fair Value Disclosure | [2] | 0 | 0 | |
Significant Other Observable Inputs (Level 2) [Member] | PSE And G [Member] | Energy-Related Contracts [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative (Liabilities) | 0 | |||
Significant Other Observable Inputs (Level 2) [Member] | PSE And G [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Other Observable Inputs (Level 2) [Member] | PSE And G [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 21 | 20 | |
Significant Other Observable Inputs (Level 2) [Member] | PSE And G [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 17 | 16 | |
Significant Other Observable Inputs (Level 2) [Member] | PSE And G [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Cash Equivalents, Fair Value Disclosure | [2] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Equity Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Government Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Other Debt Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Power [Member] | Equity Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Power [Member] | Government Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Power [Member] | Other Debt Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Power [Member] | Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Power [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Power [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Power [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | Power [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Cash Equivalents, Fair Value Disclosure | [2] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | PSE And G [Member] | Energy-Related Contracts [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative (Liabilities) | (7) | |||
Significant Unobservable Inputs (Level 3) [Member] | PSE And G [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | PSE And G [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | PSE And G [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Significant Unobservable Inputs (Level 3) [Member] | PSE And G [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Total Estimate Of Fair Value [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Cash Equivalents, Fair Value Disclosure | [2] | 226 | 365 | |
Total Estimate Of Fair Value [Member] | Energy-Related Contracts [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | 242 | [4] | 295 | |
Total Estimate Of Fair Value [Member] | Interest Rate Swap [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [5] | 11 | 22 | |
Total Estimate Of Fair Value [Member] | Equity Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 825 | 897 | |
Total Estimate Of Fair Value [Member] | Government Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 454 | 438 | |
Total Estimate Of Fair Value [Member] | Other Debt Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 401 | 339 | |
Total Estimate Of Fair Value [Member] | Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 35 | 106 | |
Total Estimate Of Fair Value [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 20 | 23 | |
Total Estimate Of Fair Value [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 106 | 91 | |
Total Estimate Of Fair Value [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 84 | 75 | |
Total Estimate Of Fair Value [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 1 | 2 | |
Total Estimate Of Fair Value [Member] | PSEG [Member] | Energy-Related Contracts [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative (Liabilities) | (93) | [4] | (165) | |
Total Estimate Of Fair Value [Member] | Power [Member] | Energy-Related Contracts [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4] | 238 | 269 | |
Total Mark-to-Market Derivative (Liabilities) | [4] | (86) | (165) | |
Total Estimate Of Fair Value [Member] | Power [Member] | Equity Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 825 | 897 | |
Total Estimate Of Fair Value [Member] | Power [Member] | Government Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 454 | 438 | |
Total Estimate Of Fair Value [Member] | Power [Member] | Other Debt Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 401 | 339 | |
Total Estimate Of Fair Value [Member] | Power [Member] | Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 35 | 106 | |
Total Estimate Of Fair Value [Member] | Power [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 5 | 5 | |
Total Estimate Of Fair Value [Member] | Power [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 26 | 21 | |
Total Estimate Of Fair Value [Member] | Power [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 21 | 18 | |
Total Estimate Of Fair Value [Member] | Power [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 1 | |
Total Estimate Of Fair Value [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Cash Equivalents, Fair Value Disclosure | [2] | 0 | 294 | |
Total Estimate Of Fair Value [Member] | PSE And G [Member] | Energy-Related Contracts [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | 4 | [4] | 26 | |
Total Mark-to-Market Derivative (Liabilities) | [4] | (7) | ||
Total Estimate Of Fair Value [Member] | PSE And G [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 4 | 5 | |
Total Estimate Of Fair Value [Member] | PSE And G [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 21 | 20 | |
Total Estimate Of Fair Value [Member] | PSE And G [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 17 | 16 | |
Total Estimate Of Fair Value [Member] | PSE And G [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3] | 0 | 0 | |
Energy-Related Contracts [Member] | Quoted Market Prices of Identical Assets (Level 1) [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4] | 0 | 0 | |
Energy-Related Contracts [Member] | Quoted Market Prices of Identical Assets (Level 1) [Member] | PSEG [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative (Liabilities) | [4] | 0 | 0 | |
Energy-Related Contracts [Member] | Quoted Market Prices of Identical Assets (Level 1) [Member] | Power [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4] | 0 | 0 | |
Total Mark-to-Market Derivative (Liabilities) | [4] | 0 | 0 | |
Energy-Related Contracts [Member] | Quoted Market Prices of Identical Assets (Level 1) [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4] | 0 | 0 | |
Energy-Related Contracts [Member] | Significant Other Observable Inputs (Level 2) [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4] | 694 | 774 | |
Energy-Related Contracts [Member] | Significant Other Observable Inputs (Level 2) [Member] | PSEG [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative (Liabilities) | [4] | (489) | (705) | |
Energy-Related Contracts [Member] | Significant Other Observable Inputs (Level 2) [Member] | Power [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4] | 694 | 774 | |
Total Mark-to-Market Derivative (Liabilities) | [4] | (489) | (705) | |
Energy-Related Contracts [Member] | Significant Other Observable Inputs (Level 2) [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4] | 0 | 0 | |
Energy-Related Contracts [Member] | Significant Unobservable Inputs (Level 3) [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4] | 9 | 38 | |
Energy-Related Contracts [Member] | Significant Unobservable Inputs (Level 3) [Member] | PSEG [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative (Liabilities) | [4] | (7) | (1) | |
Energy-Related Contracts [Member] | Significant Unobservable Inputs (Level 3) [Member] | Power [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4] | 5 | 12 | |
Total Mark-to-Market Derivative (Liabilities) | [4] | 0 | (1) | |
Energy-Related Contracts [Member] | Significant Unobservable Inputs (Level 3) [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4] | 4 | 26 | |
Interest Rate Swap [Member] | Quoted Market Prices of Identical Assets (Level 1) [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [5] | 0 | 0 | |
Interest Rate Swap [Member] | Significant Other Observable Inputs (Level 2) [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [5] | 11 | 22 | |
Interest Rate Swap [Member] | Significant Unobservable Inputs (Level 3) [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [5] | 0 | 0 | |
Assets [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Net cash collateral received in connection with net derivative contracts | (70) | (12) | ||
Other Liabilities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Net cash collateral received in connection with net derivative contracts | 12 | 36 | ||
Cash Collateral Netting [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Cash Equivalents, Fair Value Disclosure | [2],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Equity Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Government Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Other Debt Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Power [Member] | Equity Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Power [Member] | Government Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Power [Member] | Other Debt Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Power [Member] | Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Power [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Power [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Power [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Power [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Cash Equivalents, Fair Value Disclosure | [2],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | PSE And G [Member] | Energy-Related Contracts [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative (Liabilities) | 0 | |||
Cash Collateral Netting [Member] | PSE And G [Member] | Rabbi Trust - Equity Securities-Mutual Funds [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | PSE And G [Member] | Rabbi Trust - Debt Securities-Govt Obligations [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | PSE And G [Member] | Rabbi Trust - Debt Securities-Other [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | PSE And G [Member] | Rabbi Trust - Other Securities [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Fair Value, Measured on Recurring Basis, Investments | [3],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Energy-Related Contracts [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4],[6] | (461) | (517) | |
Cash Collateral Netting [Member] | Energy-Related Contracts [Member] | PSEG [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative (Liabilities) | [4],[6] | 403 | 541 | |
Cash Collateral Netting [Member] | Energy-Related Contracts [Member] | Power [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4],[6] | (461) | (517) | |
Total Mark-to-Market Derivative (Liabilities) | [4],[6] | 403 | 541 | |
Cash Collateral Netting [Member] | Energy-Related Contracts [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [4],[6] | 0 | 0 | |
Cash Collateral Netting [Member] | Interest Rate Swap [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Total Mark-to-Market Derivative Assets | [5],[6] | $ 0 | $ 0 | |
[1] | Substantially all of Power's and PSEG's derivative instruments are contracts subject to master netting agreements. Contracts not subject to master netting or similar agreements are immaterial and did not have any collateral posted or received as of September 30, 2015 and December 31, 2014. PSE&G does not have any derivative contracts subject to master netting or similar agreements. | |||
[2] | Represents money market mutual funds | |||
[3] | The NDT Fund maintains investments in various equity and fixed income securities classified as “available for sale.” The Rabbi Trust maintains investments in an S&P 500 index fund and various fixed income securities classified as “available for sale.” These securities are generally valued with prices that are either exchange provided (equity securities) or market transactions for comparable securities and/or broker quotes (fixed income securities).Level 1—Investments in marketable equity securities within the NDT Fund are primarily investments in common stocks across a broad range of industries and sectors. Most equity securities are priced utilizing the principal market close price or, in some cases, midpoint, bid or ask price. Certain open-ended mutual funds with mainly short-term investments are valued based on unadjusted quoted prices in active markets. The Rabbi Trust equity index fund is valued based on quoted prices in an active market.Level 2—NDT and Rabbi Trust fixed income securities are limited to investment grade corporate bonds, collateralized mortgage obligations, asset backed securities and government obligations or Federal Agency asset-backed securities with a wide range of maturities. Since many fixed income securities do not trade on a daily basis, they are priced using an evaluated pricing methodology that varies by asset class and reflects observable market information such as the most recent exchange price or quoted bid for similar securities. Market-based standard inputs typically include benchmark yields, reported trades, broker/dealer quotes and issuer spreads. Certain short-term investments are valued using observable market prices or market parameters such as time-to-maturity, coupon rate, quality rating and current yield. | |||
[4] | Level 2—Fair values for energy-related contracts are obtained primarily using a market-based approach. Most derivative contracts (forward purchase or sale contracts and swaps) are valued using the average of the bid/ask midpoints from multiple broker or dealer quotes or auction prices. Prices used in the valuation process are also corroborated independently by management to determine that values are based on actual transaction data or, in the absence of transactions, bid and offers for the day. Examples may include certain exchange and non-exchange traded capacity and electricity contracts and natural gas physical or swap contracts based on market prices, basis adjustments and other premiums where adjustments and premiums are not considered significant to the overall inputs.Level 3—For energy-related contracts, which include more complex agreements where limited observable inputs or pricing information are available, modeling techniques are employed using assumptions reflective of contractual terms, current market rates, forward price curves, discount rates and risk factors, as applicable. Fair values of other energy contracts may be based on broker quotes that we cannot corroborate with actual market transaction data. | |||
[5] | Interest rate swaps are valued using quoted prices on commonly quoted intervals, which are interpolated for periods different than the quoted intervals, as inputs to a market valuation model. Market inputs can generally be verified and model selection does not involve significant management judgment. | |||
[6] | Represents the netting of fair value balances with the same counterparty (where the right of offset exists) and the application of collateral. All cash collateral received or posted that has been allocated to derivative positions, where the right of offset exists, has been offset in the Condensed Consolidated Balance Sheets. As of September 30, 2015, net cash collateral (received) paid of $(58) million, was netted against the corresponding net derivative contract positions. Of the $(58) million as of September 30, 2015, $(70) million of cash collateral was netted against assets, and $12 million was netted against liabilities. As of December 31, 2014, net cash collateral (received) paid of $24 million, was netted against the corresponding net derivative contract positions. Of the $24 million as of December 31, 2014, $(12) million of cash collateral was netted against assets, and $36 million was netted against liabilities. |
Fair Value Measurements (Schedu
Fair Value Measurements (Schedule Of Quantitative Information About Level 3 Fair Value Measurements) (Detail) - USD ($) $ in Millions | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2015 | Dec. 31, 2014 | |||
Power [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Assets, Fair Value | $ 5 | $ 12 | ||
Liabilities, Fair Value | 0 | (1) | ||
PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Assets, Fair Value | 4 | 26 | ||
Liabilities, Fair Value | (7) | 0 | ||
PSEG [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Assets, Fair Value | 9 | 38 | ||
Liabilities, Fair Value | (7) | (1) | ||
Various [Member] | Power [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Assets, Fair Value | 1 | [1] | 0 | [2] |
Liabilities, Fair Value | 0 | [1] | 0 | [2] |
Electric Load Contracts [Member] | Power [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Assets, Fair Value | 4 | 12 | ||
Liabilities, Fair Value | $ 0 | $ (1) | ||
Valuation Technique (s) | Discounted Cash flow | Discounted Cash Flow | ||
Significant Unobservable Inputs | Historic Load Variability | Historic Load Variability | ||
Electric Load Contracts [Member] | Minimum [Member] | Power [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Historic Load Variability | 10.00% | 10.00% | ||
Electric Load Contracts [Member] | Maximum [Member] | Power [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Historic Load Variability | 0.00% | 0.00% | ||
Natural Gas Supply Contracts [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Assets, Fair Value | $ 4 | $ 26 | ||
Liabilities, Fair Value | $ (7) | $ 0 | ||
Valuation Technique (s) | Discounted Cash Flow | Discounted Cash Flow | ||
Significant Unobservable Inputs | Transportation Costs | Transportation Costs | ||
Natural Gas Supply Contracts [Member] | Minimum [Member] | MWh [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Transportation Costs | 0.60 | 0.70 | ||
Natural Gas Supply Contracts [Member] | Maximum [Member] | MWh [Member] | PSE And G [Member] | ||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | ||||
Transportation Costs | 0.90 | 1 | ||
[1] | Includes long-term electric positions which were immaterial as of September 30, 2015. | |||
[2] | Includes gas supply positions and long-term electric capacity positions which were immaterial as of December 31, 2014. |
Fair Value Measurements (Change
Fair Value Measurements (Changes In Level 3 Assets And (Liabilities) Measured At Fair Value On A Recurring Basis) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||||||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | ||||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||||||
Settlements | $ (2) | $ (4) | $ (18) | $ 54 | |||||
Power [Member] | |||||||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||||||
Gains and losses attributable to changes in net derivative assets and liabilities, included in Operating Income | 4 | (8) | 12 | (66) | |||||
Gains and losses attributable to changes in net derivative assets and liabilities, unrealized | 3 | (12) | (6) | (11) | |||||
Net Derivative Assets (Liabilities) [Member] | |||||||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||||||
Opening Balance | 8 | 13 | 37 | 88 | |||||
Included in Income | 4 | [1] | (8) | [1] | 12 | [1] | (66) | [2] | |
Included in Regulatory Assets/Liabilities | [3] | (8) | (9) | (29) | (81) | ||||
Purchases, (Sales) | 0 | 0 | 0 | 0 | |||||
Issuances (Settlements) | [4] | (2) | (4) | (18) | 54 | ||||
Transfers In (Out) | 0 | [5] | 0 | [5] | 0 | (3) | [5] | ||
Closing Balance | 2 | (8) | 2 | (8) | |||||
Net Derivative Assets (Liabilities) [Member] | Power [Member] | |||||||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||||||
Opening Balance | 3 | (9) | 11 | (6) | |||||
Included in Income | 4 | [1] | (8) | [1] | 12 | [1] | (66) | [2] | |
Included in Regulatory Assets/Liabilities | [3] | 0 | 0 | 0 | 0 | ||||
Purchases, (Sales) | 0 | 0 | 0 | 0 | |||||
Issuances (Settlements) | [4] | (2) | (4) | (18) | 54 | ||||
Transfers In (Out) | 0 | [5] | 0 | [5] | 0 | (3) | [5] | ||
Closing Balance | 5 | (21) | 5 | (21) | |||||
Net Derivative Assets (Liabilities) [Member] | PSE And G [Member] | |||||||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||||||
Opening Balance | 5 | 22 | 26 | 94 | |||||
Included in Income | 0 | [1] | 0 | [1] | 0 | [1] | 0 | [2] | |
Included in Regulatory Assets/Liabilities | [3] | (8) | (9) | (29) | (81) | ||||
Purchases, (Sales) | 0 | 0 | 0 | 0 | |||||
Issuances (Settlements) | [4] | 0 | 0 | 0 | 0 | ||||
Transfers In (Out) | 0 | [5] | 0 | [5] | 0 | 0 | [5] | ||
Closing Balance | $ (3) | $ 13 | $ (3) | $ 13 | |||||
[1] | PSEG’s and Power’s gains and losses attributable to changes in net derivative assets and liabilities includes $4 million and $12 million in Operating Income for the three months and nine months ended September 30, 2015, respectively. Of the $4 million in Operating Income, $3 million is unrealized. Of the $12 million in Operating Income, $(6) million is unrealized. | ||||||||
[2] | PSEG’s and Power’s gains and losses attributable to changes in net derivative assets and liabilities include $(8) million and $(66) million in Operating Income for the three months and nine months ended September 30, 2014, respectively. Of the $(8) million in Operating Income, $(12) million is unrealized. Of the $(66) million in Operating Income, $(11) million is unrealized. | ||||||||
[3] | Mainly includes gains/losses on PSE&G’s derivative contracts that are not included in either earnings or Other Comprehensive Income, as they are deferred as a Regulatory Asset/Liability and are expected to be recovered from/returned to PSE&G’s customers. | ||||||||
[4] | Represents $(2) million and $(18) million in settlements for the three months and nine months ended September 30, 2015. Includes $(4) million and $54 million in settlements for the three months and nine months ended September 30, 2014. | ||||||||
[5] | nine months ended September 30, 2014, $(3) million of net derivative assets/liabilities were transferred from Level 3 to Level 2 due to more observable pricing for the underlying securities. The transfers were recognized as of the beginning of the quarters in which the transfers first occurred as per PSEG's policy. |
Fair Value Measurements (Narrat
Fair Value Measurements (Narrative) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | Dec. 31, 2014 | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Settlements | $ (2) | $ (4) | $ (18) | $ 54 | |
Net assets measured at fair value on a recurring basis | 2,300 | 2,300 | $ 2,500 | ||
Net assets measured at fair value on a recurring basis measured using unobservable input and as Level 3 | 2 | 2 | $ 8 | ||
Power [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 3 | (12) | (6) | (11) | |
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Trading Revenue | $ 4 | $ (8) | $ 12 | (66) | |
Derivative [Member] | Power [Member] | |||||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||||
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Liability, Transfers, Net | $ (3) |
Fair Value Measurements (Fair V
Fair Value Measurements (Fair Value Of Debt) (Detail) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-Term Debt, Carrying Amount | $ 9,238 | $ 9,144 | |
Long-Term Debt, Fair Value | 10,045 | 10,149 | |
Power - Recourse Debt [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-Term Debt, Carrying Amount | [1] | 2,544 | 2,543 |
Long-Term Debt, Fair Value | [1] | 2,856 | 2,930 |
PSE And G [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-Term Debt, Carrying Amount | [1] | 6,612 | 6,312 |
Long-Term Debt, Fair Value | [1] | 7,102 | 6,912 |
Transition Funding (PSE&G) [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-Term Debt, Carrying Amount | [1] | 68 | 251 |
Long-Term Debt, Fair Value | [1] | 69 | 261 |
Transition Funding II (PSE&G) [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-Term Debt, Carrying Amount | [1] | 0 | 8 |
Long-Term Debt, Fair Value | [1] | 0 | 8 |
Energy Holdings Project Level, Non-Recourse Debt [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-Term Debt, Carrying Amount | [2] | 7 | 16 |
Long-Term Debt, Fair Value | [2] | 7 | 16 |
PSEG [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Long-Term Debt, Carrying Amount | [3] | 7 | 14 |
Long-Term Debt, Fair Value | [3] | $ 11 | $ 22 |
[1] | The debt fair valuation is based on the present value of each bond’s future cash flows. The discount rates used in the present value analysis are based on an estimate of new issue bond yields across the treasury curve. When a bond has embedded options, an interest rate model is used to reflect the impact of interest rate volatility into the analysis (primarily Level 2 measurements). | ||
[2] | Non-recourse project debt is valued as equivalent to the amortized cost and is classified as a Level 3 measurement. | ||
[3] | Fair value represents net offsets to debt resulting from adjustments from interest rate swaps entered into to hedge certain debt at Power. Carrying amount represents such fair value reduced by the unamortized premium resulting from a debt exchange entered into between Power and Energy Holdings. |
Other Income And Deductions (Sc
Other Income And Deductions (Schedule Of Other Income) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||||||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |||||
Component of Other Income [Line Items] | ||||||||
NDT Fund Gains, Interest, Dividend and Other Income | $ 24 | $ 55 | $ 78 | $ 133 | ||||
Allowance for Funds Used During Construction | 14 | 8 | 36 | 21 | ||||
Solar Loan Interest | 6 | 6 | 18 | 18 | ||||
Gain on Insurance Recovery | 28 | |||||||
Other | 3 | 6 | 11 | 13 | ||||
Total Other Income | 47 | 75 | 171 | 185 | ||||
PSE And G [Member] | ||||||||
Component of Other Income [Line Items] | ||||||||
NDT Fund Gains, Interest, Dividend and Other Income | 0 | 0 | 0 | 0 | ||||
Allowance for Funds Used During Construction | 14 | 8 | 36 | 21 | ||||
Solar Loan Interest | 6 | 6 | 18 | 18 | ||||
Gain on Insurance Recovery | 0 | |||||||
Other | 2 | 2 | 5 | 5 | ||||
Total Other Income | 22 | 16 | 59 | 44 | ||||
Power [Member] | ||||||||
Component of Other Income [Line Items] | ||||||||
NDT Fund Gains, Interest, Dividend and Other Income | 24 | 55 | 78 | 133 | ||||
Allowance for Funds Used During Construction | 0 | 0 | 0 | 0 | ||||
Solar Loan Interest | 0 | 0 | 0 | 0 | ||||
Gain on Insurance Recovery | 28 | |||||||
Other | 1 | 1 | 3 | 2 | ||||
Total Other Income | 25 | 56 | 109 | 135 | ||||
Other Entities [Member] | ||||||||
Component of Other Income [Line Items] | ||||||||
NDT Fund Gains, Interest, Dividend and Other Income | 0 | [1] | 0 | 0 | [1] | 0 | [1] | |
Allowance for Funds Used During Construction | 0 | [1] | 0 | 0 | [1] | 0 | [1] | |
Solar Loan Interest | 0 | [1] | 0 | 0 | [1] | 0 | [1] | |
Gain on Insurance Recovery | 0 | |||||||
Other | 0 | [1] | 3 | 3 | [1] | 6 | [1] | |
Total Other Income | [1] | $ 0 | $ 3 | $ 3 | $ 6 | |||
[1] | Other consists of activity at PSEG (as parent company), Energy Holdings, Services, PSEG LI and intercompany eliminations. |
Other Income And Deductions (78
Other Income And Deductions (Schedule Of Other Deductions) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | ||
Component of Other Deductions [Line Items] | |||||
NDT Fund Realized Losses and Expenses | $ 13 | $ 4 | $ 30 | $ 18 | |
Other | 1 | 5 | 6 | 13 | |
Total Other Deductions | 14 | 9 | 36 | 31 | |
PSE And G [Member] | |||||
Component of Other Deductions [Line Items] | |||||
NDT Fund Realized Losses and Expenses | 0 | 0 | 0 | 0 | |
Other | 0 | 2 | 2 | 3 | |
Total Other Deductions | 0 | 2 | 2 | 3 | |
Power [Member] | |||||
Component of Other Deductions [Line Items] | |||||
NDT Fund Realized Losses and Expenses | 13 | 4 | 30 | 18 | |
Other | 1 | 2 | 2 | 7 | |
Total Other Deductions | 14 | 6 | 32 | 25 | |
Other Entities [Member] | |||||
Component of Other Deductions [Line Items] | |||||
NDT Fund Realized Losses and Expenses | [1] | 0 | 0 | 0 | 0 |
Other | [1] | 0 | 1 | 2 | 3 |
Total Other Deductions | [1] | $ 0 | $ 1 | $ 2 | $ 3 |
[1] | Other consists of activity at PSEG (as parent company), Energy Holdings, Services, PSEG LI and intercompany eliminations. |
Income Taxes (Schedule Of Effec
Income Taxes (Schedule Of Effective Tax Rates) (Detail) | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
PSEG [Member] | ||||
Income Taxes [Line Items] | ||||
Effective tax rate | 39.40% | 37.00% | 38.80% | 37.80% |
PSE And G [Member] | ||||
Income Taxes [Line Items] | ||||
Effective tax rate | 38.20% | 38.50% | 38.70% | 38.60% |
Power [Member] | ||||
Income Taxes [Line Items] | ||||
Effective tax rate | 40.30% | 39.40% | 38.60% | 38.60% |
Income Taxes (Narrative) (Detai
Income Taxes (Narrative) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |
Sep. 30, 2015 | Sep. 30, 2015 | Sep. 09, 2014 | |
Income Taxes [Line Items] | |||
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent | 40.85% | ||
Income Tax Examination, Liability (Refund) Adjustment from Settlement with Taxing Authority | $ 121 | ||
Income Tax Examination, Tax Expense | $ (12) |
Accumulated Other Comprehensi81
Accumulated Other Comprehensive Income (Loss), Net of Tax (Changes of AOCI) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Jun. 30, 2015 | Sep. 30, 2015 | Sep. 30, 2014 | |
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | |||||
Accumulated Other Comprehensive Income (Loss), Beginning Balance | $ (277) | $ (73) | $ (283) | $ (283) | $ (95) |
Other Comprehensive Income before Reclassifications | (46) | (13) | (43) | 17 | |
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) | 24 | (13) | 27 | (21) | |
Other Comprehensive Income (Loss), net of tax | (22) | (26) | (16) | (4) | |
Accumulated Other Comprehensive Income (Loss), Ending Balance | (299) | (99) | (277) | (299) | (99) |
Cash Flow Hedges [Member] | |||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | |||||
Accumulated Other Comprehensive Income (Loss), Beginning Balance | 1 | 1 | 10 | 10 | (2) |
Other Comprehensive Income before Reclassifications | 0 | 2 | 1 | 1 | (2) |
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) | 0 | (1) | (10) | (10) | 6 |
Other Comprehensive Income (Loss), net of tax | 0 | 1 | (9) | 4 | |
Accumulated Other Comprehensive Income (Loss), Ending Balance | 1 | 2 | 1 | 1 | 2 |
Pension and OPEB Plans [Member] | |||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | |||||
Accumulated Other Comprehensive Income (Loss), Beginning Balance | (395) | (232) | (411) | (411) | (238) |
Other Comprehensive Income before Reclassifications | 0 | 0 | 0 | 0 | |
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) | 9 | 3 | 25 | 9 | |
Other Comprehensive Income (Loss), net of tax | 9 | 3 | 25 | 9 | |
Accumulated Other Comprehensive Income (Loss), Ending Balance | (386) | (229) | (395) | (386) | (229) |
Available-for-Sale Securities [Member] | |||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | |||||
Accumulated Other Comprehensive Income (Loss), Beginning Balance | 117 | 158 | 118 | 118 | 145 |
Other Comprehensive Income before Reclassifications | (46) | (15) | (44) | 19 | |
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) | 15 | (15) | 12 | (36) | |
Other Comprehensive Income (Loss), net of tax | (31) | (30) | (32) | (17) | |
Accumulated Other Comprehensive Income (Loss), Ending Balance | 86 | 128 | 117 | 86 | 128 |
Power [Member] | |||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | |||||
Accumulated Other Comprehensive Income (Loss), Beginning Balance | (223) | (44) | (228) | (228) | (63) |
Other Comprehensive Income before Reclassifications | (43) | (12) | (40) | 15 | |
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) | 21 | (15) | 23 | (23) | |
Other Comprehensive Income (Loss), net of tax | (22) | (27) | (17) | (8) | |
Accumulated Other Comprehensive Income (Loss), Ending Balance | (245) | (71) | (223) | (245) | (71) |
Power [Member] | Cash Flow Hedges [Member] | |||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | |||||
Accumulated Other Comprehensive Income (Loss), Beginning Balance | 2 | 2 | 11 | 11 | (1) |
Other Comprehensive Income before Reclassifications | 0 | 2 | 1 | (2) | |
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) | 0 | (1) | (10) | 6 | |
Other Comprehensive Income (Loss), net of tax | 0 | 1 | (9) | 4 | |
Accumulated Other Comprehensive Income (Loss), Ending Balance | 2 | 3 | 2 | 2 | 3 |
Power [Member] | Pension and OPEB Plans [Member] | |||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | |||||
Accumulated Other Comprehensive Income (Loss), Beginning Balance | (337) | (199) | (351) | (351) | (204) |
Other Comprehensive Income before Reclassifications | 0 | 0 | 0 | 0 | |
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) | 7 | 2 | 21 | 7 | |
Other Comprehensive Income (Loss), net of tax | 7 | 2 | 21 | 7 | |
Accumulated Other Comprehensive Income (Loss), Ending Balance | (330) | (197) | (337) | (330) | (197) |
Power [Member] | Available-for-Sale Securities [Member] | |||||
Accumulated Other Comprehensive Income (Loss) [Roll Forward] | |||||
Accumulated Other Comprehensive Income (Loss), Beginning Balance | 112 | 153 | 112 | 112 | 142 |
Other Comprehensive Income before Reclassifications | (43) | (14) | (41) | 17 | |
Amounts Reclassified from Accumulated Other Comprehensive Income (Loss) | 14 | (16) | 12 | (36) | |
Other Comprehensive Income (Loss), net of tax | (29) | (30) | (29) | (19) | |
Accumulated Other Comprehensive Income (Loss), Ending Balance | $ 83 | $ 123 | $ 112 | $ 83 | $ 123 |
Accumulated Other Comprehensi82
Accumulated Other Comprehensive Income (Loss), Net of Tax (Reclassifications of AOCI) (Details) - USD ($) $ in Millions | 3 Months Ended | 6 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Jun. 30, 2015 | Sep. 30, 2015 | Sep. 30, 2014 | |
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, before Tax | $ (42) | $ 28 | $ (46) | $ 51 | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Tax | 18 | (15) | 19 | (30) | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (24) | 13 | (27) | 21 | |
Cash Flow Hedges [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Energy-Related Contracts, Pre-Tax | 0 | 1 | $ 17 | 17 | (11) |
Energy-Related Contracts, Tax | 0 | 0 | (7) | 5 | |
Energy-Related Contracts, After-Tax | 0 | 1 | 10 | (6) | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 0 | 1 | $ 10 | 10 | (6) |
Pension and OPEB Plans [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification Adjustment from AOCI, Pension and OPEB, Pre-Tax | (14) | (5) | (42) | (14) | |
Reclassification Adjustment from AOCI, Pension and OPEB, Tax | 5 | 2 | 17 | 5 | |
Reclassification Adjustment from AOCI, Pension and OPEB, After-Tax | (9) | (3) | (25) | (9) | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (9) | (3) | (25) | (9) | |
Available-for-Sale Securities [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification for Available for Sale Securities, Pre-Tax | (28) | 32 | (21) | 76 | |
Reclassification for Available for Sale Securities, Tax | 13 | (17) | 9 | (40) | |
Reclassification for Available for Sale Securities, After-Tax | (15) | 15 | (12) | 36 | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (15) | 15 | (12) | 36 | |
Power [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification from Accumulated Other Comprehensive Income, Current Period, before Tax | (39) | 31 | (41) | 53 | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Tax | 18 | (16) | 18 | (30) | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (21) | 15 | (23) | 23 | |
Power [Member] | Cash Flow Hedges [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Energy-Related Contracts, Pre-Tax | 0 | 1 | 17 | (11) | |
Energy-Related Contracts, Tax | 0 | 0 | (7) | 5 | |
Energy-Related Contracts, After-Tax | 0 | 1 | 10 | (6) | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 0 | 1 | 10 | (6) | |
Power [Member] | Pension and OPEB Plans [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification Adjustment from AOCI, Pension and OPEB, Pre-Tax | (12) | (3) | (36) | (11) | |
Reclassification Adjustment from AOCI, Pension and OPEB, Tax | 5 | 1 | 15 | 4 | |
Reclassification Adjustment from AOCI, Pension and OPEB, After-Tax | (7) | (2) | (21) | (7) | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (7) | (2) | (21) | (7) | |
Power [Member] | Available-for-Sale Securities [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification for Available for Sale Securities, Pre-Tax | (27) | 33 | (22) | 75 | |
Reclassification for Available for Sale Securities, Tax | 13 | (17) | 10 | (39) | |
Reclassification for Available for Sale Securities, After-Tax | (14) | 16 | (12) | 36 | |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | (14) | 16 | (12) | 36 | |
Operating Expense [Member] | Pension and OPEB Plans [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Amortization of Prior Service (Cost) Credit, Pre-Tax | 3 | 3 | 9 | 8 | |
Amortization of Prior Service (Cost) Credit, Tax | (1) | (1) | (3) | (3) | |
Amortization of Prior Service (Cost) Credit, After-Tax | 2 | 2 | 6 | 5 | |
Amortization of Actuarial Loss, Pre-Tax | (17) | (8) | (51) | (22) | |
Amortization of Actuarial Loss, Tax | 6 | 3 | 20 | 8 | |
Amortization of Actuarial Loss, After-Tax | (11) | (5) | (31) | (14) | |
Operating Expense [Member] | Power [Member] | Pension and OPEB Plans [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Amortization of Prior Service (Cost) Credit, Pre-Tax | 3 | 3 | 9 | 7 | |
Amortization of Prior Service (Cost) Credit, Tax | (1) | (1) | (3) | (3) | |
Amortization of Prior Service (Cost) Credit, After-Tax | 2 | 2 | 6 | 4 | |
Amortization of Actuarial Loss, Pre-Tax | (15) | (6) | (45) | (18) | |
Amortization of Actuarial Loss, Tax | 6 | 2 | 18 | 7 | |
Amortization of Actuarial Loss, After-Tax | (9) | (4) | (27) | (11) | |
Operating Revenues [Member] | Cash Flow Hedges [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Energy-Related Contracts, Pre-Tax | 0 | (1) | 17 | (11) | |
Energy-Related Contracts, Tax | 0 | 0 | (7) | 5 | |
Energy-Related Contracts, After-Tax | 0 | (1) | 10 | (6) | |
Operating Revenues [Member] | Power [Member] | Cash Flow Hedges [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Energy-Related Contracts, Pre-Tax | 0 | 1 | 17 | (11) | |
Energy-Related Contracts, Tax | 0 | 0 | (7) | 5 | |
Energy-Related Contracts, After-Tax | 0 | 1 | 10 | (6) | |
Other Income [Member] | Available-for-Sale Securities [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification for Available for Sale Securities, Pre-Tax | 14 | 47 | 49 | 105 | |
Reclassification for Available for Sale Securities, Tax | (7) | (24) | (25) | (54) | |
Reclassification for Available for Sale Securities, After-Tax | 7 | 23 | 24 | 51 | |
Other Income [Member] | Power [Member] | Available-for-Sale Securities [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification for Available for Sale Securities, Pre-Tax | 14 | 45 | 47 | 101 | |
Reclassification for Available for Sale Securities, Tax | (7) | (23) | (24) | (52) | |
Reclassification for Available for Sale Securities, After-Tax | 7 | 22 | 23 | 49 | |
Other Expense [Member] | Available-for-Sale Securities [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification for Available for Sale Securities, Pre-Tax | (12) | (5) | (25) | (15) | |
Reclassification for Available for Sale Securities, Tax | 5 | 2 | 12 | 7 | |
Reclassification for Available for Sale Securities, After-Tax | (7) | (3) | (13) | (8) | |
Other Expense [Member] | Power [Member] | Available-for-Sale Securities [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification for Available for Sale Securities, Pre-Tax | (11) | (2) | (24) | (12) | |
Reclassification for Available for Sale Securities, Tax | 5 | 1 | 12 | 6 | |
Reclassification for Available for Sale Securities, After-Tax | (6) | (1) | (12) | (6) | |
Other-Than-Temporary Impairments [Member] | Available-for-Sale Securities [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification for Available for Sale Securities, Pre-Tax | (30) | (10) | (45) | (14) | |
Reclassification for Available for Sale Securities, Tax | 15 | 5 | 22 | 7 | |
Reclassification for Available for Sale Securities, After-Tax | (15) | (5) | (23) | (7) | |
Other-Than-Temporary Impairments [Member] | Power [Member] | Available-for-Sale Securities [Member] | |||||
Reclassification out of Accumulated Other Comprehensive Income [Line Items] | |||||
Reclassification for Available for Sale Securities, Pre-Tax | (30) | (10) | (45) | (14) | |
Reclassification for Available for Sale Securities, Tax | 15 | 5 | 22 | 7 | |
Reclassification for Available for Sale Securities, After-Tax | $ (15) | $ (5) | $ (23) | $ (7) |
Earnings Per Share (EPS) And 83
Earnings Per Share (EPS) And Dividends (Basic And Diluted Earnings Per Share Computation) (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Net Income | $ 439 | $ 444 | $ 1,370 | $ 1,042 |
Weighted Average Common Shares Outstanding, Basic (shares) | 505 | 506 | 505 | 506 |
Effect of Stock Based Compensation Awards, Basic (shares) | 0 | 0 | 0 | 0 |
Total Shares, Basic (shares) | 505 | 506 | 505 | 506 |
Net Income, Basic (in dollars per share) | $ 0.87 | $ 0.88 | $ 2.71 | $ 2.06 |
Weighted Average Common Shares Outstanding, Diluted (shares) | 505 | 506 | 505 | 506 |
Effect of Stock Based Compensation Awards, Diluted (shares) | 3 | 1 | 3 | 1 |
Total Shares, Diluted (shares) | 508 | 507 | 508 | 507 |
Net Income, Diluted (in dollars per share) | $ 0.87 | $ 0.87 | $ 2.70 | $ 2.05 |
Earnings Per Share (EPS) And 84
Earnings Per Share (EPS) And Dividends (Dividend Payments On Common Stock) (Detail) - USD ($) $ / shares in Units, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Earnings Per Share [Abstract] | ||||
DIVIDENDS PAID PER SHARE OF COMMON STOCK (in dollars per share) | $ 0.39 | $ 0.37 | $ 1.17 | $ 1.11 |
Dividend Payments on Common Stock | $ 198 | $ 187 | $ 592 | $ 561 |
Financial Information By Busi85
Financial Information By Business Segments (Financial Information By Business Segments) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | Dec. 31, 2014 | ||
Segment Reporting Information [Line Items] | ||||||
Operating Revenues | $ 2,688 | $ 2,641 | $ 8,137 | $ 8,113 | ||
Net Income (Loss) | 439 | 444 | 1,370 | 1,042 | ||
Property, Plant and Equipment, Additions | 1,039 | 693 | 2,782 | 1,922 | ||
Total Assets | 36,424 | 36,424 | $ 35,333 | |||
Investments in Equity Method Subsidiaries | 117 | 117 | 123 | |||
Operating Segments [Member] | PSE And G [Member] | ||||||
Segment Reporting Information [Line Items] | ||||||
Operating Revenues | 1,766 | 1,655 | 5,234 | 5,235 | ||
Net Income (Loss) | 222 | 200 | 631 | 565 | ||
Property, Plant and Equipment, Additions | 716 | 497 | 1,946 | 1,493 | ||
Total Assets | 22,909 | 22,909 | 22,223 | |||
Investments in Equity Method Subsidiaries | 0 | 0 | 0 | |||
Operating Segments [Member] | Power [Member] | ||||||
Segment Reporting Information [Line Items] | ||||||
Operating Revenues | 1,096 | 1,138 | 3,846 | 3,824 | ||
Net Income (Loss) | 206 | 222 | 707 | 440 | ||
Property, Plant and Equipment, Additions | 310 | 188 | 797 | 414 | ||
Total Assets | 12,314 | 12,314 | 12,046 | |||
Investments in Equity Method Subsidiaries | 116 | 116 | 121 | |||
Operating Segments [Member] | Other [Member] | ||||||
Segment Reporting Information [Line Items] | ||||||
Operating Revenues | [1] | 120 | 123 | 326 | 359 | |
Net Income (Loss) | [1] | 11 | 22 | 32 | 37 | |
Property, Plant and Equipment, Additions | [1] | 13 | 8 | 39 | 15 | |
Total Assets | [1] | 2,775 | 2,775 | 2,799 | ||
Investments in Equity Method Subsidiaries | [1] | 1 | 1 | 2 | ||
Eliminations [Member] | ||||||
Segment Reporting Information [Line Items] | ||||||
Operating Revenues | [2] | (294) | (275) | (1,269) | (1,305) | |
Net Income (Loss) | [2] | 0 | 0 | 0 | 0 | |
Property, Plant and Equipment, Additions | [2] | 0 | $ 0 | 0 | $ 0 | |
Total Assets | [2] | (1,574) | (1,574) | (1,735) | ||
Investments in Equity Method Subsidiaries | [2] | $ 0 | $ 0 | $ 0 | ||
[1] | Includes amounts applicable to Energy Holdings and PSEG LI, which are below the quantitative threshold for separate disclosure as reportable segments. Other also includes amounts applicable to PSEG (parent corporation) and Services. | |||||
[2] | Intercompany eliminations, primarily related to intercompany transactions between PSE&G and Power. No gains or losses are recorded on any intercompany transactions; rather, all intercompany transactions are at cost or, in the case of the BGS and BGSS contracts between PSE&G and Power, at rates prescribed by the BPU. For a further discussion of the intercompany transactions between PSE&G and Power, see Note 17. Related-Party Transactions. |
Related-Party Transactions (Sch
Related-Party Transactions (Schedule Of Related Party Transactions, Revenue) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | ||||
PSE And G [Member] | |||||||
Related Party Transaction [Line Items] | |||||||
Billings from Power through BGS and BGSS | [1] | $ 294 | $ 280 | $ 1,287 | $ 1,308 | ||
Administrative Billings from Services | [2] | 66 | 59 | 197 | 183 | ||
Total Billings from Affiliates | 360 | 339 | 1,484 | 1,491 | |||
Power [Member] | |||||||
Related Party Transaction [Line Items] | |||||||
Revenue from Related Parties | 294 | 280 | 1,287 | [1] | 1,308 | [1] | |
Administrative Billings from Services | $ 44 | $ 41 | $ 135 | [2] | $ 129 | [2] | |
[1] | PSE&G has entered into a requirements contract with Power under which Power provides the gas supply services needed to meet PSE&G’s BGSS and other contractual requirements. Power has also entered into contracts to supply energy, capacity and ancillary services to PSE&G through the BGS auction process. | ||||||
[2] | Services provides and bills administrative services to PSE&G and Power at cost. In addition, PSE&G and Power have other payables to Services, including amounts related to certain common costs, such as pension and OPEB costs, which Services pays on behalf of each of the operating companies. |
Related-Party Transactions (S87
Related-Party Transactions (Schedule Of Related Party Transactions, Payables) (Detail) - PSE And G [Member] - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 | |
Related Party Transaction [Line Items] | |||
Receivable From PSEG | [1] | $ 7 | $ 274 |
Payable To Power | [2] | 158 | 313 |
Payable To Services | [3] | 50 | 66 |
Accounts Payable - Affiliated Companies | 208 | 379 | |
Working Capital Advances to Services | [4] | 33 | 33 |
Long-Term Accrued Taxes Payable | $ 165 | $ 116 | |
[1] | PSEG files a consolidated federal income tax return with its affiliated companies. A tax allocation agreement exists between PSEG and each of its affiliated companies. The general operation of these agreements is that the subsidiary company will compute its taxable income on a stand-alone basis. If the result is a net tax liability, such amount shall be paid to PSEG. If there are net operating losses and/or tax credits, the subsidiary shall receive payment for the tax savings from PSEG to the extent that PSEG is able to utilize those benefits. | ||
[2] | PSE&G has entered into a requirements contract with Power under which Power provides the gas supply services needed to meet PSE&G’s BGSS and other contractual requirements. Power has also entered into contracts to supply energy, capacity and ancillary services to PSE&G through the BGS auction process. | ||
[3] | Services provides and bills administrative services to PSE&G and Power at cost. In addition, PSE&G and Power have other payables to Services, including amounts related to certain common costs, such as pension and OPEB costs, which Services pays on behalf of each of the operating companies. | ||
[4] | PSE&G and Power have advanced working capital to Services. The amounts are included in Other Noncurrent Assets on PSE&G’s and Power’s Condensed Consolidated Balance Sheets. |
Related-Party Transactions (S88
Related-Party Transactions (Schedule Of Related Party Transactions, Receivables) (Detail) - Power [Member] - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 | |
Related Party Transaction [Line Items] | |||
Receivable from PSE&G | [1] | $ 158 | $ 313 |
Payable To Services | [2] | 26 | 23 |
Payable to PSEG | [3] | 91 | 95 |
Accounts Payable - Affiliated Companies | 117 | 118 | |
Short Term Loan To Affiliate | [4] | 865 | 584 |
Working Capital Advances to Services | [5] | 17 | 17 |
Long-Term Accrued Taxes Payable | $ 54 | $ 41 | |
[1] | PSE&G has entered into a requirements contract with Power under which Power provides the gas supply services needed to meet PSE&G’s BGSS and other contractual requirements. Power has also entered into contracts to supply energy, capacity and ancillary services to PSE&G through the BGS auction process. | ||
[2] | Services provides and bills administrative services to PSE&G and Power at cost. In addition, PSE&G and Power have other payables to Services, including amounts related to certain common costs, such as pension and OPEB costs, which Services pays on behalf of each of the operating companies. | ||
[3] | PSEG files a consolidated federal income tax return with its affiliated companies. A tax allocation agreement exists between PSEG and each of its affiliated companies. The general operation of these agreements is that the subsidiary company will compute its taxable income on a stand-alone basis. If the result is a net tax liability, such amount shall be paid to PSEG. If there are net operating losses and/or tax credits, the subsidiary shall receive payment for the tax savings from PSEG to the extent that PSEG is able to utilize those benefits. | ||
[4] | Power’s short-term loans with PSEG are for working capital and other short-term needs. Interest Income and Interest Expense relating to these short-term funding activities were immaterial. | ||
[5] | PSE&G and Power have advanced working capital to Services. The amounts are included in Other Noncurrent Assets on PSE&G’s and Power’s Condensed Consolidated Balance Sheets. |
Guarantees Of Debt (Schedule Of
Guarantees Of Debt (Schedule Of Financial Statements Of Guarantors) (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | Dec. 31, 2014 | |
Debt Instrument [Line Items] | |||||
Operating Revenues | $ 2,688 | $ 2,641 | $ 8,137 | $ 8,113 | |
Operating Expenses | 1,874 | 1,895 | 5,707 | 6,297 | |
Operating Income (Loss) | 814 | 746 | 2,430 | 1,816 | |
Equity Earnings (Losses) of Subsidiaries | 3 | 3 | 10 | 10 | |
Other Income | 47 | 75 | 171 | 185 | |
Other Deductions | (14) | (9) | (36) | (31) | |
Other-Than Temporary Impairments | 30 | 10 | 45 | 14 | |
Interest Expense | (96) | (100) | (291) | (291) | |
Income Tax Expense | (285) | (261) | (869) | (633) | |
Net Income | 439 | 444 | 1,370 | 1,042 | |
Net Cash Provided By (Used In) Operating Activities | 3,228 | 2,536 | |||
Net Cash Provided By (Used In) Investing Activities | (2,841) | (1,988) | |||
Net Cash Provided By (Used In) Financing Activities | (518) | (338) | |||
Current Assets | 3,204 | 3,204 | $ 4,119 | ||
Property, Plant and Equipment, net | 25,605 | 25,605 | 23,589 | ||
Noncurrent Assets | 7,615 | 7,615 | 7,625 | ||
Total Assets | 36,424 | 36,424 | 35,333 | ||
Current Liabilities | 3,604 | 3,604 | 3,478 | ||
Noncurrent Liabilities | 11,754 | 11,754 | 11,408 | ||
Long-Term Debt | 8,132 | 8,132 | 8,261 | ||
Member's Equity | 12,934 | 12,934 | 12,186 | ||
TOTAL LIABILITIES AND CAPITALIZATION | 36,424 | 36,424 | 35,333 | ||
Power Senior Notes [Member] | |||||
Debt Instrument [Line Items] | |||||
Operating Revenues | 1,096 | 1,138 | 3,846 | 3,824 | |
Operating Expenses | 705 | 785 | 2,643 | 3,122 | |
Operating Income (Loss) | 391 | 353 | 1,203 | 702 | |
Equity Earnings (Losses) of Subsidiaries | 3 | 4 | 11 | 11 | |
Other Income | 25 | 56 | 109 | 135 | |
Other Deductions | (14) | (6) | (32) | (25) | |
Other-Than Temporary Impairments | 30 | 10 | 45 | 14 | |
Interest Expense | (30) | (31) | (94) | (92) | |
Income Tax Expense | (139) | (144) | (445) | (277) | |
Net Income | 206 | 222 | 707 | 440 | |
Comprehensive Income (Loss) | 184 | 195 | 690 | 432 | |
Net Cash Provided By (Used In) Operating Activities | 1,558 | 1,110 | |||
Net Cash Provided By (Used In) Investing Activities | (1,150) | (326) | |||
Net Cash Provided By (Used In) Financing Activities | (402) | (778) | |||
Current Assets | 2,224 | 2,224 | 2,359 | ||
Property, Plant and Equipment, net | 7,907 | 7,907 | 7,515 | ||
Investment in Subsidiaries | 0 | 0 | 0 | ||
Noncurrent Assets | 2,183 | 2,183 | 2,172 | ||
Total Assets | 12,314 | 12,314 | 12,046 | ||
Current Liabilities | 1,574 | 1,574 | 1,184 | ||
Noncurrent Liabilities | 3,200 | 3,200 | 3,061 | ||
Long-Term Debt | 1,691 | 1,691 | 2,243 | ||
Member's Equity | 5,849 | 5,849 | 5,558 | ||
TOTAL LIABILITIES AND CAPITALIZATION | 12,314 | 12,314 | 12,046 | ||
Power Senior Notes [Member] | Power Parent [Member] | |||||
Debt Instrument [Line Items] | |||||
Operating Revenues | 0 | 0 | 0 | 0 | |
Operating Expenses | 3 | 3 | 7 | 12 | |
Operating Income (Loss) | (3) | (3) | (7) | (12) | |
Equity Earnings (Losses) of Subsidiaries | 220 | 225 | 755 | 459 | |
Other Income | 10 | 9 | 33 | 25 | |
Other Deductions | 0 | (3) | (1) | (7) | |
Other-Than Temporary Impairments | 0 | 0 | 0 | 0 | |
Interest Expense | (28) | (24) | (90) | (79) | |
Income Tax Expense | 7 | 18 | 17 | 54 | |
Net Income | 206 | 222 | 707 | 440 | |
Comprehensive Income (Loss) | 184 | 195 | 690 | 432 | |
Net Cash Provided By (Used In) Operating Activities | 435 | 471 | |||
Net Cash Provided By (Used In) Investing Activities | (656) | 187 | |||
Net Cash Provided By (Used In) Financing Activities | 221 | (652) | |||
Current Assets | 4,678 | 4,678 | 4,263 | ||
Property, Plant and Equipment, net | 82 | 82 | 81 | ||
Investment in Subsidiaries | 4,555 | 4,555 | 4,516 | ||
Noncurrent Assets | 264 | 264 | 278 | ||
Total Assets | 9,579 | 9,579 | 9,138 | ||
Current Liabilities | 1,581 | 1,581 | 883 | ||
Noncurrent Liabilities | 458 | 458 | 454 | ||
Long-Term Debt | 1,691 | 1,691 | 2,243 | ||
Member's Equity | 5,849 | 5,849 | 5,558 | ||
TOTAL LIABILITIES AND CAPITALIZATION | 9,579 | 9,579 | 9,138 | ||
Power Senior Notes [Member] | Guarantor Subsidiaries [Member] | |||||
Debt Instrument [Line Items] | |||||
Operating Revenues | 1,084 | 1,125 | 3,811 | 3,781 | |
Operating Expenses | 692 | 772 | 2,610 | 3,079 | |
Operating Income (Loss) | 392 | 353 | 1,201 | 702 | |
Equity Earnings (Losses) of Subsidiaries | (2) | (1) | (4) | (4) | |
Other Income | 26 | 55 | 111 | 135 | |
Other Deductions | (14) | (4) | (31) | (18) | |
Other-Than Temporary Impairments | 30 | 10 | 45 | 14 | |
Interest Expense | (8) | (10) | (24) | (23) | |
Income Tax Expense | (148) | (161) | (463) | (329) | |
Net Income | 216 | 222 | 745 | 449 | |
Comprehensive Income (Loss) | 187 | 191 | 707 | 433 | |
Net Cash Provided By (Used In) Operating Activities | 1,826 | 1,252 | |||
Net Cash Provided By (Used In) Investing Activities | (1,382) | (559) | |||
Net Cash Provided By (Used In) Financing Activities | (446) | (693) | |||
Current Assets | 1,786 | 1,786 | 2,037 | ||
Property, Plant and Equipment, net | 6,390 | 6,390 | 6,265 | ||
Investment in Subsidiaries | 349 | 349 | 120 | ||
Noncurrent Assets | 1,962 | 1,962 | 1,952 | ||
Total Assets | 10,487 | 10,487 | 10,374 | ||
Current Liabilities | 3,595 | 3,595 | 3,606 | ||
Noncurrent Liabilities | 2,563 | 2,563 | 2,442 | ||
Long-Term Debt | 0 | 0 | 0 | ||
Member's Equity | 4,329 | 4,329 | 4,326 | ||
TOTAL LIABILITIES AND CAPITALIZATION | 10,487 | 10,487 | 10,374 | ||
Power Senior Notes [Member] | Non-Guarantor Subsidiaries [Member] | |||||
Debt Instrument [Line Items] | |||||
Operating Revenues | 37 | 36 | 144 | 118 | |
Operating Expenses | 35 | 32 | 135 | 106 | |
Operating Income (Loss) | 2 | 4 | 9 | 12 | |
Equity Earnings (Losses) of Subsidiaries | 3 | 4 | 11 | 11 | |
Other Income | 0 | 0 | 0 | 0 | |
Other Deductions | 0 | 0 | 0 | 0 | |
Other-Than Temporary Impairments | 0 | 0 | 0 | 0 | |
Interest Expense | (5) | (4) | (15) | (14) | |
Income Tax Expense | 2 | (1) | 1 | (2) | |
Net Income | 2 | 3 | 6 | 7 | |
Comprehensive Income (Loss) | 2 | 3 | 6 | 7 | |
Net Cash Provided By (Used In) Operating Activities | 66 | 53 | |||
Net Cash Provided By (Used In) Investing Activities | (303) | (24) | |||
Net Cash Provided By (Used In) Financing Activities | 245 | (29) | |||
Current Assets | 134 | 134 | 150 | ||
Property, Plant and Equipment, net | 1,435 | 1,435 | 1,169 | ||
Investment in Subsidiaries | 0 | 0 | 0 | ||
Noncurrent Assets | 133 | 133 | 137 | ||
Total Assets | 1,702 | 1,702 | 1,456 | ||
Current Liabilities | 772 | 772 | 786 | ||
Noncurrent Liabilities | 355 | 355 | 360 | ||
Long-Term Debt | 0 | 0 | 0 | ||
Member's Equity | 575 | 575 | 310 | ||
TOTAL LIABILITIES AND CAPITALIZATION | 1,702 | 1,702 | 1,456 | ||
Power Senior Notes [Member] | Consolidating Adjustments [Member] | |||||
Debt Instrument [Line Items] | |||||
Operating Revenues | (25) | (23) | (109) | (75) | |
Operating Expenses | (25) | (22) | (109) | (75) | |
Operating Income (Loss) | 0 | (1) | 0 | 0 | |
Equity Earnings (Losses) of Subsidiaries | (218) | (224) | (751) | (455) | |
Other Income | (11) | (8) | (35) | (25) | |
Other Deductions | 0 | 1 | 0 | 0 | |
Other-Than Temporary Impairments | 0 | 0 | 0 | 0 | |
Interest Expense | 11 | 7 | 35 | 24 | |
Income Tax Expense | 0 | 0 | 0 | 0 | |
Net Income | (218) | (225) | (751) | (456) | |
Comprehensive Income (Loss) | (189) | $ (194) | (713) | (440) | |
Net Cash Provided By (Used In) Operating Activities | (769) | (666) | |||
Net Cash Provided By (Used In) Investing Activities | 1,191 | 70 | |||
Net Cash Provided By (Used In) Financing Activities | (422) | $ 596 | |||
Current Assets | (4,374) | (4,374) | (4,091) | ||
Property, Plant and Equipment, net | 0 | 0 | 0 | ||
Investment in Subsidiaries | (4,904) | (4,904) | (4,636) | ||
Noncurrent Assets | (176) | (176) | (195) | ||
Total Assets | (9,454) | (9,454) | (8,922) | ||
Current Liabilities | (4,374) | (4,374) | (4,091) | ||
Noncurrent Liabilities | (176) | (176) | (195) | ||
Long-Term Debt | 0 | 0 | 0 | ||
Member's Equity | (4,904) | (4,904) | (4,636) | ||
TOTAL LIABILITIES AND CAPITALIZATION | $ (9,454) | $ (9,454) | $ (8,922) |