0001109357exc:PotomacElectricPowerCompanyMemberus-gaap:OperatingSegmentsMemberexc:AlternativeRevenueProgramsMemberus-gaap:RegulatedOperationMember2021-04-012021-06-30CommonwealthEdisonCoMemberexc:OtherReceivablesMember2022-01-012022-03-31
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
| | |
| ☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the Quarterly Period Ended June 30, 2022March 31, 2023
or
| | |
| ☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
| | | | | | | | | | | | | | |
| Commission File Number | | Name of Registrant; State or Other Jurisdiction of Incorporation; Address of Principal Executive Offices; and Telephone Number | | IRS Employer Identification Number |
| | | | |
| 001-16169 | | EXELON CORPORATION | | 23-2990190 |
| | (a Pennsylvania corporation) 10 South Dearborn Street P.O. Box 805379 Chicago, Illinois 60680-5379 (800) 483-3220 | | |
| | | | |
| 001-01839 | | COMMONWEALTH EDISON COMPANY | | 36-0938600 |
| | (an Illinois corporation) 10 South Dearborn Street Chicago, Illinois 60603-2300 (312) 394-4321 | | |
| | | | |
| 000-16844 | | PECO ENERGY COMPANY | | 23-0970240 |
| | (a Pennsylvania corporation) P.O. Box 8699 2301 Market Street Philadelphia, Pennsylvania 19101-8699 (215) 841-4000 | | |
| | | | |
| 001-01910 | | BALTIMORE GAS AND ELECTRIC COMPANY | | 52-0280210 |
| | (a Maryland corporation) 2 Center Plaza 110 West Fayette Street Baltimore, Maryland 21201-3708 (410) 234-5000 | | |
| | | | |
| 001-31403 | | PEPCO HOLDINGS LLC | | 52-2297449 |
| | (a Delaware limited liability company) 701 Ninth Street, N.W. Washington, District of Columbia 20068-0001 (202) 872-2000 | | |
| | | | |
| 001-01072 | | POTOMAC ELECTRIC POWER COMPANY | | 53-0127880 |
| | (a District of Columbia and Virginia corporation) 701 Ninth Street, N.W. Washington, District of Columbia 20068-001 (202) 872-2000 | | |
| | | | |
| 001-01405 | | DELMARVA POWER & LIGHT COMPANY | | 51-0084283 |
| | (a Delaware and Virginia corporation) 500 North Wakefield Drive Newark, Delaware 19702-5440 (202) 872-2000 | | |
| | | | |
| 001-03559 | | ATLANTIC CITY ELECTRIC COMPANY | | 21-0398280 |
| | (a New Jersey corporation) 500 North Wakefield Drive Newark, Delaware 19702-5440 (202) 872-2000 | | |
Securities registered pursuant to Section 12(b) of the Act:
| | | | | | | | | | | | | | |
| Title of each class | | Trading Symbol(s) | | Name of each exchange on which registered |
| EXELON CORPORATION: | | | | |
| Common stock, without par value | | EXC | | The Nasdaq Stock Market LLC |
| | | | |
| PECO ENERGY COMPANY: | | | | |
| Trust Receipts of PECO Energy Capital Trust III, each representing a 7.38% Cumulative Preferred Security, Series D, $25 stated value, issued by PECO Energy Capital, L.P. and unconditionally guaranteed by PECO Energy Company | | EXC/28 | | New York Stock Exchange |
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No o
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No o
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and "emerging growth company" in Rule 12b-2 of the Exchange Act.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Exelon Corporation | Large Accelerated Filer | x | Accelerated Filer | ☐ | Non-accelerated Filer | ☐ | Smaller Reporting Company | ☐ | Emerging Growth Company | ☐ |
| Commonwealth Edison Company | Large Accelerated Filer | ☐ | Accelerated Filer | ☐ | Non-accelerated Filer | x | Smaller Reporting Company | ☐ | Emerging Growth Company | ☐ |
| PECO Energy Company | Large Accelerated Filer | ☐ | Accelerated Filer | ☐ | Non-accelerated Filer | x | Smaller Reporting Company | ☐ | Emerging Growth Company | ☐ |
| Baltimore Gas and Electric Company | Large Accelerated Filer | ☐ | Accelerated Filer | ☐ | Non-accelerated Filer | x | Smaller Reporting Company | ☐ | Emerging Growth Company | ☐ |
| Pepco Holdings LLC | Large Accelerated Filer | ☐ | Accelerated Filer | ☐ | Non-accelerated Filer | x | Smaller Reporting Company | ☐ | Emerging Growth Company | ☐ |
| Potomac Electric Power Company | Large Accelerated Filer | ☐ | Accelerated Filer | ☐ | Non-accelerated Filer | x | Smaller Reporting Company | ☐ | Emerging Growth Company | ☐ |
| Delmarva Power & Light Company | Large Accelerated Filer | ☐ | Accelerated Filer | ☐ | Non-accelerated Filer | x | Smaller Reporting Company | ☐ | Emerging Growth Company | ☐ |
| Atlantic City Electric Company | Large Accelerated Filer | ☐ | Accelerated Filer | ☐ | Non-accelerated Filer | x | Smaller Reporting Company | ☐ | Emerging Growth Company | ☐ |
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes ☐ No x
The number of shares outstanding of each registrant’s common stock as of June 30, 2022March 31, 2023 was:
| | | | | |
| Exelon Corporation Common Stock, without par value | 980,472,436994,568,998 |
| Commonwealth Edison Company Common Stock, $12.50 par value | 127,021,391127,021,394 |
| PECO Energy Company Common Stock, without par value | 170,478,507 |
| Baltimore Gas and Electric Company Common Stock, without par value | 1,000 |
| Pepco Holdings LLC | not applicable |
| Potomac Electric Power Company Common Stock, $0.01 par value | 100 |
| Delmarva Power & Light Company Common Stock, $2.25 par value | 1,000 |
| Atlantic City Electric Company Common Stock, $3.00 par value | 8,546,017 |
TABLE OF CONTENTS
| | | | | | | | |
| GLOSSARY OF TERMS AND ABBREVIATIONS |
| Exelon Corporation and Related Entities |
| Exelon | | Exelon Corporation |
| ComEd | | Commonwealth Edison Company |
| PECO | | PECO Energy Company |
| BGE | | Baltimore Gas and Electric Company |
| Pepco Holdings or PHI | | Pepco Holdings LLC |
| Pepco | | Potomac Electric Power Company |
| DPL | | Delmarva Power & Light Company |
| ACE | | Atlantic City Electric Company |
| Registrants | | Exelon, ComEd, PECO, BGE, PHI, Pepco, DPL, and ACE, collectively |
| Utility Registrants | | ComEd, PECO, BGE, Pepco, DPL, and ACE, collectively |
ACE Funding or ATF | | Atlantic City Electric Transition Funding LLC |
| | |
| BSC | | Exelon Business Services Company, LLC |
| Exelon Corporate | | Exelon in its corporate capacity as a holding company |
| PCI | | Potomac Capital Investment Corporation and its subsidiaries |
| PECO Trust III | | PECO Energy Capital Trust III |
| PECO Trust IV | | PECO Energy Capital Trust IV |
| | |
| PHI Corporate | | PHI in its corporate capacity as a holding company |
| PHISCO | | PHI Service Company |
| Former Related Entities |
| Constellation | | Constellation Energy Corporation |
| Generation | | Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC, a subsidiary of Exelon prior to separation on February 1, 2022) |
| | |
| | | | | | | | |
| GLOSSARY OF TERMS AND ABBREVIATIONS |
| Other Terms and Abbreviations | | |
2021 Form 10-K | | The Registrants' Annual Report on Form 10-K for the year ended December 31, 2021 filed with the SEC on February 25, 2022 |
2021 Recast Form 10-K | | The Registrants' Current Report on Form 8-K filed with the SEC on June 30, 2022 to recast Exelon's consolidated financial statements and certain other financial information originally included in the 2021 Form 10-K |
Note - of the 2021 Recast2022 Form 10-K | | Reference to specific Combined Note to Consolidated Financial Statements in the 2021 Recastwithin Exelon's 2022 Annual Report on Form 10-K |
AECABO | | Accumulated Benefit Obligation |
| AECs | | Alternative Energy CreditCredits that isare issued for each megawatt hour of generation from a qualified alternative energy source |
| AFUDC | | Allowance for Funds Used During Construction |
| AMI | | Advanced Metering Infrastructure |
| AOCI | | Accumulated Other Comprehensive Income (Loss) |
| ARO | | Asset Retirement Obligation |
| BGS | | Basic Generation Service |
| BSA | | Bill Stabilization Adjustment |
CEJA (formerly Clean Energy Law in the Exelon 2021 Form 10-K) | | Climate and Equitable Jobs Act; Illinois Public Act 102-0662 signed into law on September 15, 2021 |
| CERCLA | | Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended |
| CIP | | Conservation Incentive Program |
| CMC | | Carbon Mitigation Credit |
CODMCODMs | | Chief Operating Decision Maker(s) |
| DC PLUG | | District of Columbia Power Line Undergrounding Initiative |
| DCPSC | | Public Service Commission of the District of Columbia |
| DEPSC | | Delaware Public Service Commission |
| DOEE | | District of Columbia Department of Energy & Environment |
| DPA | | Deferred Prosecution Agreement |
| DPP | | Deferred Purchase Price |
| DSIC | | Distribution System Improvement Charge |
| EIMA | | Energy Infrastructure Modernization Act (Illinois Senate Bill 1652 and Illinois House Bill 3036) |
| EPA | | United States Environmental Protection Agency |
| ERCOT | | Electric Reliability Council of Texas |
| ERISA | | Employee Retirement Income Security Act of 1974, as amended |
| ERP | | Enterprise Resource Program |
| ETAC | | Energy Transition Assistance Charge |
| FEJA | | Illinois Public Act 99-0906 or Future Energy Jobs Act |
| FERC | | Federal Energy Regulatory Commission |
| GAAP | | Generally Accepted Accounting Principles in the United States |
| GCR | | Gas Cost Rate |
| GSA | | Generation Supply Adjustment |
GWhGWhs | | Gigawatt hourhours |
| ICC | | Illinois Commerce Commission |
| IIJA | | Infrastructure Investment and Jobs Act |
| Illinois Settlement Legislation | | Legislation enacted in 2007 affecting electric utilities in Illinois |
| IPA | | Illinois Power Agency |
| IRA | | Inflation Reduction Act |
| IRC | | Internal Revenue Code |
| IRS | | Internal Revenue Service |
LIBOR | | London Interbank Offered Rate |
| MDPSC | | Maryland Public Service Commission |
| MGP | | Manufactured Gas Plant |
mmcf | | Million Cubic Feet |
| | | | | | | | |
| GLOSSARY OF TERMS AND ABBREVIATIONS |
| Other Terms and Abbreviations | | |
MWmmcf | | MegawattMillion Cubic Feet |
| MMG | | Middle Mile Grant |
| MRP | | Multi-Year Rate Plan |
| | |
| MWh | | Megawatt hour |
| N/A | | Not applicable |
| NAV | | Net Asset Value |
| NDT | | Nuclear Decommissioning Trust |
| NJBPU | | New Jersey Board of Public Utilities |
| NPNS | | Normal Purchase Normal Sale scope exception |
| NPS | | National Park Service |
| NRD | | Natural Resources Damages |
| OCI | | Other Comprehensive Income |
| OPEB | | Other Postretirement Employee Benefits |
| PAPUC | | Pennsylvania Public Utility Commission |
| PGC | | Purchased Gas Cost Clause |
| PJM | | PJM Interconnection, LLC |
| POLR | | Provider of Last Resort |
| PPA | | Power Purchase Agreement |
| PP&E | | Property, plant, and equipment |
PRPPRPs | | Potentially Responsible Parties |
| REC | | Renewable Energy Credit which is issued for each megawatt hour of generation from a qualified renewable energy source |
| Regulatory Agreement Units | | Nuclear generating units or portions thereof whose decommissioning-related activities are subject to contractual elimination under regulatory accounting |
| RFP | | Request for Proposal |
| Rider | | Reconcilable Surcharge Recovery Mechanism |
| ROE | | Return on equity |
| ROU | | Right-of-use |
| RPS | | Renewable Energy Portfolio Standards |
| RTO | | Regional Transmission Organization |
| SEC | | United States Securities and Exchange Commission |
| SOFR | | Secured Overnight Financing Rate |
| SOS | | Standard Offer Service |
| STRIDE | | Maryland Strategic Infrastructure Development and Enhancement Program |
| TCJA | | Tax Cuts and Jobs Act |
Transition Bonds | | Transition Bonds issued by ACE Funding |
| ZEC | | Zero Emission Credit or Zero Emission Certificate |
FILING FORMAT
This combined Form 10-Q is being filed separately by Exelon Corporation, Commonwealth Edison Company, PECO Energy Company, Baltimore Gas and Electric Company, Pepco Holdings LLC, Potomac Electric Power Company, Delmarva Power & Light Company, and Atlantic City Electric Company (Registrants). Information contained herein relating to any individual Registrant is filed by such Registrant on its own behalf. No Registrant makes any representation as to information relating to any other Registrant.
CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING INFORMATION
This Report contains certain forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995 that are subject to risks and uncertainties. Words such as “could,” “may,” “expects,” “anticipates,” “will,” “targets,” “goals,” “projects,” “intends,” “plans,” “believes,” “seeks,” “estimates,” “predicts,” "should," and variations on such words, and similar expressions that reflect our current views with respect to future events and operational, economic, and financial performance, are intended to identify such forward-looking statements.
The factors that could cause actual results to differ materially from the forward-looking statements made by the Registrants include those factors discussed herein, as well as the items discussed in (1) the 20212022 Form 10-K in (a) Part I, ITEM 1A. Risk Factors; (2) the 2021 Recast Form 10-K in (a)Factors, (b) Part II, ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (b)(c) Part II, ITEM 8. Financial Statements and Supplementary Data: Note 17,18, Commitments and Contingencies; (3)(2) this Quarterly Report on Form 10-Q in (a) Part II, ITEM 1A. Risk Factors, (b) Part I, ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) Part I, ITEM 1. Financial Statements: Note 12, Commitments and Contingencies; and (4)(3) other factors discussed in filings with the SEC by the Registrants.
Investors are cautioned not to place undue reliance on these forward-looking statements, which apply only as of the date of this Report. None of the Registrants undertakes any obligation to publicly release any revision to its forward-looking statements to reflect events or circumstances after the date of this Report.
WHERE TO FIND MORE INFORMATION
The SEC maintains an Internet site at www.sec.gov that contains reports, proxy and information statements, and other information that the Registrants file electronically with the SEC. These documents are also available to the public from commercial document retrieval services and the Registrants' website at www.exeloncorp.com. Information contained on the Registrants' website shall not be deemed incorporated into, or to be a part of, this Report.
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended
June 30, | | Six Months Ended
June 30, |
| (In millions, except per share data) | 2022 | | 2021 | | 2022 | | 2021 |
| Operating revenues | | | | | | | |
| Electric operating revenues | $ | 3,934 | | | $ | 3,739 | | | $ | 8,415 | | | $ | 7,609 | |
| Natural gas operating revenues | 307 | | | 234 | | | 1,124 | | | 867 | |
| Revenues from alternative revenue programs | (2) | | | 47 | | | 27 | | | 176 | |
| Total operating revenues | 4,239 | | | 4,020 | | | 9,566 | | | 8,652 | |
| Operating expenses | | | | | | | |
| Purchased power | 1,167 | | | 1,006 | | | 2,748 | | | 2,146 | |
| Purchased fuel | 107 | | | 58 | | | 445 | | | 276 | |
| Purchased power and fuel from affiliates | — | | | 257 | | | 159 | | | 550 | |
| Operating and maintenance | 1,109 | | | 1,073 | | | 2,288 | | | 2,155 | |
| Depreciation and amortization | 830 | | | 736 | | | 1,647 | | | 1,494 | |
| Taxes other than income taxes | 330 | | | 314 | | | 684 | | | 631 | |
| Total operating expenses | 3,543 | | | 3,444 | | | 7,971 | | | 7,252 | |
| | | | | | | |
| (Loss) gain on sales of assets and businesses | (2) | | | 4 | | | (2) | | | 4 | |
| | | | | | | |
| | | | | | | |
| Operating income | 694 | | | 580 | | | 1,593 | | | 1,404 | |
| Other income and (deductions) | | | | | | | |
| Interest expense, net | (352) | | | (318) | | | (684) | | | (630) | |
| Interest expense to affiliates | (6) | | | (6) | | | (13) | | | (13) | |
| Other, net | 175 | | | 73 | | | 313 | | | 131 | |
| Total other income and (deductions) | (183) | | | (251) | | | (384) | | | (512) | |
| Income from continuing operations before income taxes | 511 | | | 329 | | | 1,209 | | | 892 | |
| Income taxes | 46 | | | 3 | | | 263 | | | 42 | |
| Equity in earnings of unconsolidated affiliates | — | | | — | | | — | | | 1 | |
| Net income from continuing operations after income taxes | 465 | | | 326 | | | 946 | | | 851 | |
| Net income (loss) from discontinued operations after income taxes (Note 2) | — | | | 150 | | | 117 | | | (640) | |
| Net income | 465 | | | 476 | | | 1,063 | | | 211 | |
| Net income attributable to noncontrolling interests | — | | | 75 | | | 1 | | | 99 | |
| Net income attributable to common shareholders | $ | 465 | | | $ | 401 | | | $ | 1,062 | | | $ | 112 | |
| | | | | | | |
| Amounts attributable to common shareholders: | | | | | | | |
| Net income from continuing operations | 465 | | | 326 | | | 946 | | | 851 | |
| Net income (loss) from discontinued operations | — | | | 75 | | | 116 | | | (739) | |
| Net income attributable to common shareholders | $ | 465 | | | $ | 401 | | | $ | 1,062 | | | $ | 112 | |
| | | | | | | |
| Comprehensive income, net of income taxes | | | | | | | |
| Net income | $ | 465 | | | $ | 476 | | | $ | 1,063 | | | $ | 211 | |
| Other comprehensive income (loss), net of income taxes | | | | | | | |
| Pension and non-pension postretirement benefit plans: | | | | | | | |
| Prior service benefit reclassified to periodic benefit cost | 2 | | | (1) | | | 2 | | | (2) | |
| Actuarial loss reclassified to periodic benefit cost | 10 | | | 56 | | | 24 | | | 112 | |
| Pension and non-pension postretirement benefit plan valuation adjustment | — | | | — | | | — | | | (2) | |
| | | | | | | |
| | | | | | | |
| Unrealized gain on foreign currency translation | — | | | 2 | | | — | | | 3 | |
| | | | | | | |
| Other comprehensive income | 12 | | | 57 | | | 26 | | | 111 | |
| Comprehensive income | 477 | | | 533 | | | 1,089 | | | 322 | |
| Comprehensive income attributable to noncontrolling interests | — | | | 75 | | | 1 | | | 99 | |
| Comprehensive income attributable to common shareholders | $ | 477 | | | $ | 458 | | | $ | 1,088 | | | $ | 223 | |
| | | | | | | |
| Average shares of common stock outstanding: | | | | | | | |
| Basic | 981 | | | 978 | | | 981 | | | 978 | |
| Assumed exercise and/or distributions of stock-based awards | 1 | | | 1 | | | 1 | | | 1 | |
Diluted(a) | 982 | | | 979 | | | 982 | | | 979 | |
| | | | | | | |
| Earnings per average common share from continuing operations | | | | | | | |
| Basic | $ | 0.47 | | | $ | 0.33 | | | $ | 0.96 | | | $ | 0.87 | |
| Diluted | $ | 0.47 | | | $ | 0.33 | | | $ | 0.96 | | | $ | 0.87 | |
| | | | | | | |
| Earnings (losses) per average common share from discontinued operations | | | | | | | |
| Basic | $ | — | | | $ | 0.08 | | | $ | 0.12 | | | $ | (0.76) | |
| Diluted | $ | — | | | $ | 0.08 | | | $ | 0.12 | | | $ | (0.76) | |
__________ | | | | | | | | | | | | | | | |
| | | Three Months Ended
March 31, |
| (In millions, except per share data) | | | | | 2023 | | 2022 |
| Operating revenues | | | | | | | |
| Electric operating revenues | | | | | $ | 4,462 | | | $ | 4,481 | |
| Natural gas operating revenues | | | | | 822 | | | 817 | |
| Revenues from alternative revenue programs | | | | | 279 | | | 29 | |
| Total operating revenues | | | | | 5,563 | | | 5,327 | |
| Operating expenses | | | | | | | |
| Purchased power | | | | | 1,733 | | | 1,581 | |
| Purchased fuel | | | | | 358 | | | 338 | |
| Purchased power and fuel from affiliates | | | | | — | | | 159 | |
| Operating and maintenance | | | | | 1,151 | | | 1,178 | |
| Depreciation and amortization | | | | | 860 | | | 817 | |
| Taxes other than income taxes | | | | | 355 | | | 354 | |
| Total operating expenses | | | | | 4,457 | | | 4,427 | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| Operating income | | | | | 1,106 | | | 900 | |
| Other income and (deductions) | | | | | | | |
| Interest expense, net | | | | | (406) | | | (332) | |
| Interest expense to affiliates | | | | | (6) | | | (6) | |
| Other, net | | | | | 109 | | | 137 | |
| Total other income and (deductions) | | | | | (303) | | | (201) | |
| Income from continuing operations before income taxes | | | | | 803 | | | 699 | |
| Income taxes | | | | | 134 | | | 218 | |
| | | | | | | |
| Net income from continuing operations after income taxes | | | | | 669 | | | 481 | |
| Net income from discontinued operations after income taxes (Note 2) | | | | | — | | | 117 | |
| Net income | | | | | 669 | | | 598 | |
| Net income attributable to noncontrolling interests | | | | | — | | | 1 | |
| Net income attributable to common shareholders | | | | | $ | 669 | | | $ | 597 | |
| | | | | | | |
| Amounts attributable to common shareholders: | | | | | | | |
| Net income from continuing operations | | | | | 669 | | | 481 | |
| Net income from discontinued operations | | | | | — | | | 116 | |
| Net income attributable to common shareholders | | | | | $ | 669 | | | $ | 597 | |
| | | | | | | |
| Comprehensive income, net of income taxes | | | | | | | |
| Net income | | | | | $ | 669 | | | $ | 598 | |
| Other comprehensive income (loss), net of income taxes | | | | | | | |
| Pension and non-pension postretirement benefit plans: | | | | | | | |
| | | | | | | |
| Actuarial loss reclassified to periodic benefit cost | | | | | 3 | | | 14 | |
| Pension and non-pension postretirement benefit plan valuation adjustment | | | | | (10) | | | — | |
| Unrealized gain on cash flow hedges | | | | | 6 | | | — | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| Other comprehensive (loss) income | | | | | (1) | | | 14 | |
| Comprehensive income | | | | | 668 | | | 612 | |
| Comprehensive income attributable to noncontrolling interests | | | | | — | | | 1 | |
| Comprehensive income attributable to common shareholders | | | | | $ | 668 | | | $ | 611 | |
| | | | | | | |
| Average shares of common stock outstanding: | | | | | | | |
| Basic | | | | | 995 | | | 981 | |
| Assumed exercise and/or distributions of stock-based awards | | | | | 1 | | | — | |
| Diluted | | | | | 996 | | | 981 | |
| | | | | | | |
| Earnings per average common share from continuing operations | | | | | | | |
| Basic | | | | | $ | 0.67 | | | $ | 0.49 | |
| Diluted | | | | | $ | 0.67 | | | $ | 0.49 | |
| | | | | | | |
| Earnings per average common share from discontinued operations | | | | | | | |
| Basic | | | | | $ | — | | | $ | 0.12 | |
| Diluted | | | | | $ | — | | | $ | 0.12 | |
(a)The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect were none for the three and six months ended June 30, 2022 and 2021, respectively.
See the Combined Notes to Consolidated Financial Statements
9
EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
| | | Six Months Ended
June 30, | | Three Months Ended
March 31, |
| (In millions) | (In millions) | 2022 | | 2021 | (In millions) | 2023 | | 2022 |
| Cash flows from operating activities | Cash flows from operating activities | | | | Cash flows from operating activities | | | |
| Net income | Net income | $ | 1,063 | | | $ | 211 | | Net income | $ | 669 | | | $ | 598 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | Adjustments to reconcile net income to net cash flows provided by operating activities: | | Adjustments to reconcile net income to net cash flows provided by operating activities: | |
| Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization | Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization | 1,854 | | | 4,180 | | Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization | 860 | | | 1,024 | |
| Asset impairments | — | | | 500 | | |
| | | Gain on sales of assets and businesses | Gain on sales of assets and businesses | (8) | | | (83) | | Gain on sales of assets and businesses | — | | | (10) | |
| | Deferred income taxes and amortization of investment tax credits | Deferred income taxes and amortization of investment tax credits | 143 | | | (163) | | Deferred income taxes and amortization of investment tax credits | 113 | | | 110 | |
| Net fair value changes related to derivatives | Net fair value changes related to derivatives | (59) | | | (490) | | Net fair value changes related to derivatives | — | | | (59) | |
| Net realized and unrealized losses (gains) on NDT funds | 205 | | | (376) | | |
| Net unrealized losses (gains) on equity investments | 16 | | | (96) | | |
| Net realized and unrealized losses on NDT funds | | Net realized and unrealized losses on NDT funds | — | | | 205 | |
| Net unrealized losses on equity investments | | Net unrealized losses on equity investments | — | | | 16 | |
| Other non-cash operating activities | Other non-cash operating activities | 276 | | | (331) | | Other non-cash operating activities | (138) | | | 232 | |
| Changes in assets and liabilities: | Changes in assets and liabilities: | | Changes in assets and liabilities: | |
| Accounts receivable | Accounts receivable | (795) | | | (16) | | Accounts receivable | 106 | | | (711) | |
| Inventories | Inventories | 12 | | | 1 | | Inventories | 102 | | | 125 | |
| Accounts payable and accrued expenses | Accounts payable and accrued expenses | 544 | | | (87) | | Accounts payable and accrued expenses | (482) | | | 291 | |
| Option premiums (paid) received, net | (39) | | | 2 | | |
| Collateral received, net | 1,689 | | | 957 | | |
| Option premiums paid, net | | Option premiums paid, net | — | | | (39) | |
| Collateral (paid) received, net | | Collateral (paid) received, net | (214) | | | 1,142 | |
| Income taxes | Income taxes | 23 | | | 190 | | Income taxes | 23 | | | 77 | |
| Regulatory assets and liabilities, net | Regulatory assets and liabilities, net | (376) | | | (276) | | Regulatory assets and liabilities, net | (324) | | | (31) | |
| Pension and non-pension postretirement benefit contributions | Pension and non-pension postretirement benefit contributions | (585) | | | (559) | | Pension and non-pension postretirement benefit contributions | (44) | | | (574) | |
| Other assets and liabilities | Other assets and liabilities | (723) | | | (2,426) | | Other assets and liabilities | (187) | | | (614) | |
| Net cash flows provided by operating activities | Net cash flows provided by operating activities | 3,240 | | | 1,138 | | Net cash flows provided by operating activities | 484 | | | 1,782 | |
| Cash flows from investing activities | Cash flows from investing activities | | | | Cash flows from investing activities | | | |
| Capital expenditures | Capital expenditures | (3,507) | | | (4,040) | | Capital expenditures | (1,881) | | | (1,922) | |
| Proceeds from NDT fund sales | Proceeds from NDT fund sales | 488 | | | 4,438 | | Proceeds from NDT fund sales | — | | | 488 | |
| Investment in NDT funds | Investment in NDT funds | (516) | | | (4,538) | | Investment in NDT funds | — | | | (516) | |
| Collection of DPP | Collection of DPP | 169 | | | 2,209 | | Collection of DPP | — | | | 169 | |
| | Proceeds from sales of assets and businesses | Proceeds from sales of assets and businesses | 16 | | | 724 | | Proceeds from sales of assets and businesses | — | | | 16 | |
| | Other investing activities | Other investing activities | 4 | | | 17 | | Other investing activities | 10 | | | (54) | |
| Net cash flows used in investing activities | Net cash flows used in investing activities | (3,346) | | | (1,190) | | Net cash flows used in investing activities | (1,871) | | | (1,819) | |
| Cash flows from financing activities | Cash flows from financing activities | | | | Cash flows from financing activities | | | |
| Changes in short-term borrowings | Changes in short-term borrowings | (597) | | | (666) | | Changes in short-term borrowings | (1,130) | | | (700) | |
| Proceeds from short-term borrowings with maturities greater than 90 days | Proceeds from short-term borrowings with maturities greater than 90 days | 1,150 | | | 500 | | Proceeds from short-term borrowings with maturities greater than 90 days | — | | | 1,150 | |
| Repayments on short-term borrowings with maturities greater than 90 days | Repayments on short-term borrowings with maturities greater than 90 days | (350) | | | — | | Repayments on short-term borrowings with maturities greater than 90 days | (150) | | | (350) | |
| Issuance of long-term debt | Issuance of long-term debt | 5,151 | | | 2,455 | | Issuance of long-term debt | 3,925 | | | 4,301 | |
| Retirement of long-term debt | Retirement of long-term debt | (1,707) | | | (630) | | Retirement of long-term debt | (857) | | | (6) | |
| | Dividends paid on common stock | Dividends paid on common stock | (663) | | | (747) | | Dividends paid on common stock | (358) | | | (332) | |
| | Proceeds from employee stock plans | Proceeds from employee stock plans | 17 | | | 47 | | Proceeds from employee stock plans | 10 | | | 9 | |
| Transfer of cash, restricted cash, and cash equivalents to Constellation | Transfer of cash, restricted cash, and cash equivalents to Constellation | (2,594) | | | — | | Transfer of cash, restricted cash, and cash equivalents to Constellation | — | | | (2,594) | |
| Other financing activities | Other financing activities | (84) | | | (64) | | Other financing activities | (60) | | | (62) | |
| Net cash flows provided by financing activities | Net cash flows provided by financing activities | 323 | | | 895 | | Net cash flows provided by financing activities | 1,380 | | | 1,416 | |
| Increase in cash, restricted cash, and cash equivalents | 217 | | | 843 | | |
| (Decrease) increase in cash, restricted cash, and cash equivalents | | (Decrease) increase in cash, restricted cash, and cash equivalents | (7) | | | 1,379 | |
| Cash, restricted cash, and cash equivalents at beginning of period | Cash, restricted cash, and cash equivalents at beginning of period | 1,619 | | | 1,166 | | Cash, restricted cash, and cash equivalents at beginning of period | 1,090 | | | 1,619 | |
| Cash, restricted cash, and cash equivalents at end of period | Cash, restricted cash, and cash equivalents at end of period | $ | 1,836 | | | $ | 2,009 | | Cash, restricted cash, and cash equivalents at end of period | $ | 1,083 | | | $ | 2,998 | |
| | Supplemental cash flow information | Supplemental cash flow information | | Supplemental cash flow information | |
| Decrease in capital expenditures not paid | Decrease in capital expenditures not paid | $ | (276) | | | $ | (313) | | Decrease in capital expenditures not paid | $ | (201) | | | $ | (322) | |
| Increase in DPP | Increase in DPP | 348 | | | 1,958 | | Increase in DPP | — | | | 348 | |
| (Decrease) increase in PP&E related to ARO update | (335) | | | 2 | | |
| Decrease in PP&E related to ARO update | | Decrease in PP&E related to ARO update | — | | | (335) | |
See the Combined Notes to Consolidated Financial Statements
10
EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | (In millions) | (In millions) | June 30, 2022 | | December 31, 2021 | (In millions) | March 31, 2023 | | December 31, 2022 |
| ASSETS | ASSETS | | | | ASSETS | | | |
| Current assets | Current assets | | Current assets | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 816 | | | $ | 672 | | Cash and cash equivalents | $ | 522 | | | $ | 407 | |
| Restricted cash and cash equivalents | Restricted cash and cash equivalents | 961 | | | 321 | | Restricted cash and cash equivalents | 381 | | | 566 | |
| | Accounts receivable | Accounts receivable | | Accounts receivable | |
| Customer accounts receivable | Customer accounts receivable | 2,219 | | 2,189 | Customer accounts receivable | 2,493 | | 2,544 |
| Customer allowance for credit losses | Customer allowance for credit losses | (354) | | (320) | Customer allowance for credit losses | (389) | | (327) |
| Customer accounts receivable, net | Customer accounts receivable, net | 1,865 | | | 1,869 | | Customer accounts receivable, net | 2,104 | | | 2,217 | |
| Other accounts receivable | Other accounts receivable | 1,403 | | 1,068 | Other accounts receivable | 1,346 | | 1,426 |
| Other allowance for credit losses | Other allowance for credit losses | (81) | | (72) | Other allowance for credit losses | (91) | | (82) |
| Other accounts receivable, net | Other accounts receivable, net | 1,322 | | | 996 | | Other accounts receivable, net | 1,255 | | | 1,344 | |
| Inventories, net | Inventories, net | | Inventories, net | |
| Fossil fuel | Fossil fuel | 133 | | | 105 | | Fossil fuel | 70 | | | 208 | |
| Materials and supplies | Materials and supplies | 491 | | | 476 | | Materials and supplies | 582 | | | 547 | |
| Regulatory assets | Regulatory assets | 1,239 | | | 1,296 | | Regulatory assets | 2,386 | | | 1,641 | |
| Other | Other | 515 | | | 387 | | Other | 477 | | | 406 | |
| Current assets of discontinued operations | — | | | 7,835 | | |
| Total current assets | Total current assets | 7,342 | | | 13,957 | | Total current assets | 7,777 | | | 7,336 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $15,242 and $14,430 as of June 30, 2022 and December 31, 2021, respectively) | 66,456 | | | 64,558 | | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $16,384 and $15,930 as of March 31, 2023 and December 31, 2022, respectively) | | Property, plant, and equipment (net of accumulated depreciation and amortization of $16,384 and $15,930 as of March 31, 2023 and December 31, 2022, respectively) | 70,117 | | | 69,076 | |
| Deferred debits and other assets | Deferred debits and other assets | | Deferred debits and other assets | |
| Regulatory assets | Regulatory assets | 8,350 | | | 8,224 | | Regulatory assets | 7,878 | | | 8,037 | |
| Goodwill | Goodwill | 6,630 | | | 6,630 | | Goodwill | 6,630 | | | 6,630 | |
| Receivable related to Regulatory Agreement Units | Receivable related to Regulatory Agreement Units | 2,265 | | | — | | Receivable related to Regulatory Agreement Units | 3,069 | | | 2,897 | |
| Investments | Investments | 235 | | | 250 | | Investments | 234 | | | 232 | |
| Other | Other | 1,017 | | | 885 | | Other | 1,220 | | | 1,141 | |
| Property, plant, and equipment, deferred debits, and other assets of discontinued operations | — | | | 38,509 | | |
| Total deferred debits and other assets | Total deferred debits and other assets | 18,497 | | | 54,498 | | Total deferred debits and other assets | 19,031 | | | 18,937 | |
| Total assets | Total assets | $ | 92,295 | | | $ | 133,013 | | Total assets | $ | 96,925 | | | $ | 95,349 | |
See the Combined Notes to Consolidated Financial Statements
11
EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | (In millions) | (In millions) | June 30, 2022 | | December 31, 2021 | (In millions) | March 31, 2023 | | December 31, 2022 |
| LIABILITIES AND SHAREHOLDERS’ EQUITY | LIABILITIES AND SHAREHOLDERS’ EQUITY | | | | LIABILITIES AND SHAREHOLDERS’ EQUITY | | | |
| Current liabilities | Current liabilities | | Current liabilities | |
| Short-term borrowings | Short-term borrowings | $ | 2,003 | | | $ | 1,248 | | Short-term borrowings | $ | 1,306 | | | $ | 2,586 | |
| Long-term debt due within one year | Long-term debt due within one year | 505 | | | 2,153 | | Long-term debt due within one year | 1,356 | | | 1,802 | |
| Accounts payable | Accounts payable | 2,451 | | | 2,379 | | Accounts payable | 2,762 | | | 3,382 | |
| Accrued expenses | Accrued expenses | 1,057 | | | 1,137 | | Accrued expenses | 1,183 | | | 1,226 | |
| Payables to affiliates | Payables to affiliates | 5 | | | 5 | | Payables to affiliates | 5 | | | 5 | |
| Regulatory liabilities | Regulatory liabilities | 411 | | | 376 | | Regulatory liabilities | 472 | | | 437 | |
| Mark-to-market derivative liabilities | Mark-to-market derivative liabilities | — | | | 18 | | Mark-to-market derivative liabilities | 23 | | | 8 | |
| Unamortized energy contract liabilities | Unamortized energy contract liabilities | 11 | | | 89 | | Unamortized energy contract liabilities | 9 | | | 10 | |
| Other | Other | 1,588 | | | 766 | | Other | 976 | | | 1,155 | |
| Current liabilities of discontinued operations | — | | | 7,940 | | |
| Total current liabilities | Total current liabilities | 8,031 | | | 16,111 | | Total current liabilities | 8,092 | | | 10,611 | |
| Long-term debt | Long-term debt | 35,789 | | | 30,749 | | Long-term debt | 38,732 | | | 35,272 | |
| Long-term debt to financing trusts | Long-term debt to financing trusts | 390 | | | 390 | | Long-term debt to financing trusts | 390 | | | 390 | |
| Deferred credits and other liabilities | Deferred credits and other liabilities | | Deferred credits and other liabilities | |
| Deferred income taxes and unamortized investment tax credits | Deferred income taxes and unamortized investment tax credits | 11,240 | | | 10,611 | | Deferred income taxes and unamortized investment tax credits | 11,483 | | | 11,250 | |
| Regulatory liabilities | Regulatory liabilities | 8,513 | | | 9,628 | | Regulatory liabilities | 9,307 | | | 9,112 | |
| Pension obligations | Pension obligations | 1,406 | | | 2,051 | | Pension obligations | 1,101 | | | 1,109 | |
| Non-pension postretirement benefit obligations | Non-pension postretirement benefit obligations | 800 | | | 811 | | Non-pension postretirement benefit obligations | 506 | | | 507 | |
| Asset retirement obligations | Asset retirement obligations | 275 | | | 271 | | Asset retirement obligations | 270 | | | 269 | |
| Mark-to-market derivative liabilities | Mark-to-market derivative liabilities | 103 | | | 201 | | Mark-to-market derivative liabilities | 77 | | | 83 | |
| Unamortized energy contract liabilities | Unamortized energy contract liabilities | 38 | | | 146 | | Unamortized energy contract liabilities | 32 | | | 35 | |
| | Other | Other | 2,054 | | | 1,573 | | Other | 1,869 | | | 1,967 | |
| Long-term debt, deferred credits, and other liabilities of discontinued operations | — | | | 25,676 | | |
| Total deferred credits and other liabilities | Total deferred credits and other liabilities | 24,429 | | | 50,968 | | Total deferred credits and other liabilities | 24,645 | | | 24,332 | |
| Total liabilities | Total liabilities | 68,639 | | | 98,218 | | Total liabilities | 71,859 | | | 70,605 | |
| Commitments and contingencies | Commitments and contingencies | 0 | | 0 | Commitments and contingencies | | | |
| | Shareholders’ equity | Shareholders’ equity | | Shareholders’ equity | |
| Common stock (No par value, 2,000 shares authorized, 980 shares and 979 shares outstanding at June 30, 2022 and December 31, 2021, respectively) | 20,319 | | | 20,324 | | |
| Treasury stock, at cost (2 shares at June 30, 2022 and December 31, 2021) | (123) | | | (123) | | |
| Common stock (No par value, 2,000 shares authorized, 994 shares outstanding as of March 31, 2023 and December 31, 2022) | | Common stock (No par value, 2,000 shares authorized, 994 shares outstanding as of March 31, 2023 and December 31, 2022) | 20,921 | | | 20,908 | |
| Treasury stock, at cost (2 shares as of March 31, 2023 and December 31, 2022) | | Treasury stock, at cost (2 shares as of March 31, 2023 and December 31, 2022) | (123) | | | (123) | |
| Retained earnings | Retained earnings | 4,161 | | | 16,942 | | Retained earnings | 4,907 | | | 4,597 | |
| Accumulated other comprehensive loss, net | Accumulated other comprehensive loss, net | (701) | | | (2,750) | | Accumulated other comprehensive loss, net | (639) | | | (638) | |
| Total shareholders’ equity | Total shareholders’ equity | 23,656 | | | 34,393 | | Total shareholders’ equity | 25,066 | | | 24,744 | |
| Noncontrolling interests | — | | | 402 | | |
| Total equity | 23,656 | | | 34,795 | | |
| | Total liabilities and shareholders’ equity | Total liabilities and shareholders’ equity | $ | 92,295 | | | $ | 133,013 | | Total liabilities and shareholders’ equity | $ | 96,925 | | | $ | 95,349 | |
See the Combined Notes to Consolidated Financial Statements
12
EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY
(Unaudited)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2022 |
(In millions, shares
in thousands) | Issued
Shares | | Common
Stock | | Treasury
Stock | | Retained
Earnings | | Accumulated
Other
Comprehensive
Loss, net | | Noncontrolling
Interests | | Total Shareholders'
Equity |
| Balance, December 31, 2021 | 981,291 | | | $ | 20,324 | | | $ | (123) | | | $ | 16,942 | | | $ | (2,750) | | | $ | 402 | | | $ | 34,795 | |
| Net income | — | | | — | | | — | | | 597 | | | — | | | 1 | | | 598 | |
| Long-term incentive plan activity | 540 | | | (13) | | | — | | | — | | | — | | | — | | | (13) | |
| Employee stock purchase plan issuances | 211 | | | 9 | | | — | | | — | | | — | | | — | | | 9 | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| Changes in equity of noncontrolling interests | — | | | — | | | — | | | — | | | — | | | (7) | | | (7) | |
| | | | | | | | | | | | | |
| Distribution of Constellation (Note 2) | — | | | (21) | | | — | | | (13,179) | | | 2,023 | | | (396) | | | (11,573) | |
Common stock dividends ($0.34/common share) | — | | | — | | | — | | | (332) | | | — | | | — | | | (332) | |
| Other comprehensive income, net of income taxes | — | | | — | | | — | | | — | | | 14 | | | — | | | 14 | |
| | | | | | | | | | | | | |
| Balance, March 31, 2022 | 982,042 | | | $ | 20,299 | | | $ | (123) | | | $ | 4,028 | | | $ | (713) | | | $ | — | | | $ | 23,491 | |
| Net income | — | | | — | | | — | | | 465 | | | — | | | — | | | 465 | |
| Long-term incentive plan activity | 21 | | | 10 | | | — | | | — | | | — | | | — | | | 10 | |
| Employee stock purchase plan issuances | 242 | | | 10 | | | — | | | — | | | — | | | — | | | 10 | |
| | | | | | | | | | | | | |
| Changes in equity of noncontrolling interests | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
Common stock dividends ($0.34/common share) | — | | | — | | | — | | | (332) | | | — | | | — | | | (332) | |
| Other comprehensive income, net of income taxes | — | | | — | | | — | | | — | | | 12 | | | — | | | 12 | |
| | | | | | | | | | | | | |
| Balance, June 30, 2022 | 982,305 | | | $ | 20,319 | | | $ | (123) | | | $ | 4,161 | | | $ | (701) | | | $ | — | | | $ | 23,656 | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
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| | | | | | | | | | | | | |
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| | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended March 31, 2023 |
(In millions, shares
in thousands) | Issued
Shares | | Common
Stock | | Treasury
Stock | | Retained
Earnings | | Accumulated
Other
Comprehensive
Loss, net | | Noncontrolling
Interests | | Total Shareholders'
Equity |
| Balance, December 31, 2022 | 995,830 | | | $ | 20,908 | | | $ | (123) | | | $ | 4,597 | | | $ | (638) | | | $ | — | | | $ | 24,744 | |
| Net income | — | | | — | | | — | | | 669 | | | — | | | — | | | 669 | |
| Long-term incentive plan activity | 306 | | | 1 | | | — | | | — | | | — | | | — | | | 1 | |
| Employee stock purchase plan issuances | 266 | | | 12 | | | — | | | — | | | — | | | — | | | 12 | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
Common stock dividends ($0.36/common share) | — | | | — | | | — | | | (359) | | | | | — | | | (359) | |
| Other comprehensive loss, net of income taxes | — | | | — | | | — | | | — | | | (1) | | | — | | | (1) | |
| | | | | | | | | | | | | |
| Balance, March 31, 2023 | 996,402 | | | $ | 20,921 | | | $ | (123) | | | $ | 4,907 | | | $ | (639) | | | $ | — | | | $ | 25,066 | |
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| | | | | | | | | | | | | |
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| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended March 31, 2022 |
(In millions, shares
in thousands) | Issued
Shares | | Common
Stock | | Treasury
Stock | | Retained
Earnings | | Accumulated
Other
Comprehensive
Loss, net | | Noncontrolling
Interests | | Total Shareholders'
Equity |
| Balance, December 31, 2021 | 981,291 | | | $ | 20,324 | | | $ | (123) | | | $ | 16,942 | | | $ | (2,750) | | | $ | 402 | | | $ | 34,795 | |
| Net income | — | | | — | | | — | | | 597 | | | — | | | 1 | | | 598 | |
| Long-term incentive plan activity | 540 | | | (13) | | | — | | | — | | | — | | | — | | | (13) | |
| Employee stock purchase plan issuances | 211 | | | 9 | | | — | | | — | | | — | | | — | | | 9 | |
| | | | | | | | | | | | | |
| Changes in equity of noncontrolling interests | — | | | — | | | — | | | — | | | — | | | (7) | | | (7) | |
| | | | | | | | | | | | | |
| Distribution of Constellation (Note 2) | — | | | (21) | | | — | | | (13,179) | | | 2,023 | | | (396) | | | (11,573) | |
Common stock dividends ($0.34/common share) | — | | | — | | | — | | | (332) | | | — | | | — | | | (332) | |
| Other comprehensive income, net of income taxes | — | | | — | | | — | | | — | | | 14 | | | — | | | 14 | |
| | | | | | | | | | | | | |
| Balance, March 31, 2022 | 982,042 | | | $ | 20,299 | | | $ | (123) | | | $ | 4,028 | | | $ | (713) | | | $ | — | | | $ | 23,491 | |
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See the Combined Notes to Consolidated Financial Statements
13
EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY
(Unaudited)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2021 |
(In millions, shares
in thousands) | Issued
Shares | | Common
Stock | | Treasury
Stock | | Retained
Earnings | | Accumulated
Other
Comprehensive
Loss, net | | Noncontrolling
Interests | | Total Shareholders'
Equity |
| Balance, December 31, 2020 | 977,466 | | | $ | 19,373 | | | $ | (123) | | | $ | 16,735 | | | $ | (3,400) | | | $ | 2,283 | | | $ | 34,868 | |
| Net (loss) income | — | | | — | | | — | | | (289) | | | — | | | 25 | | | (264) | |
| Long-term incentive plan activity | 640 | | | 5 | | | — | | | — | | | — | | | — | | | 5 | |
| Employee stock purchase plan issuances | 902 | | | 34 | | | — | | | — | | | — | | | — | | | 34 | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| Changes in equity of noncontrolling interests | — | | | — | | | — | | | — | | | — | | | (10) | | | (10) | |
| | | | | | | | | | | | | |
Common stock dividends ($0.38/common share) | — | | | — | | | — | | | (374) | | | — | | | — | | | (374) | |
| Other comprehensive income, net of income taxes | — | | | — | | | — | | | — | | | 54 | | | — | | | 54 | |
| | | | | | | | | | | | | |
| Balance, March 31, 2021 | 979,008 | | | $ | 19,412 | | | $ | (123) | | | $ | 16,072 | | | $ | (3,346) | | | $ | 2,298 | | | $ | 34,313 | |
| Net income | — | | | — | | | — | | | 401 | | | — | | | 75 | | | 476 | |
| Long-term incentive plan activity | 237 | | | 24 | | | — | | | — | | | — | | | — | | | 24 | |
| Employee stock purchase plan issuances | 420 | | | 18 | | | — | | | — | | | — | | | — | | | 18 | |
| | | | | | | | | | | | | |
| Changes in equity of noncontrolling interests | — | | | — | | | — | | | — | | | — | | | (13) | | | (13) | |
| | | | | | | | | | | | | |
Common stock dividends ($0.38/common share) | — | | | — | | | — | | | (375) | | | — | | | — | | | (375) | |
| Other comprehensive income, net of income taxes | — | | | — | | | — | | | — | | | 57 | | | — | | | 57 | |
| Balance, June 30, 2021 | 979,665 | | | $ | 19,454 | | | $ | (123) | | | $ | 16,098 | | | $ | (3,289) | | | $ | 2,360 | | | $ | 34,500 | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
See the Combined Notes to Consolidated Financial Statements
14
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended
June 30, | | Six Months Ended
June 30, |
| (In millions) | 2022 | | 2021 | | 2022 | | 2021 |
| Operating revenues | | | | | | | |
| Electric operating revenues | $ | 1,387 | | | $ | 1,503 | | | $ | 3,075 | | | $ | 2,977 | |
| Revenues from alternative revenue programs | 35 | | | 9 | | | 75 | | | 64 | |
| Operating revenues from affiliates | 3 | | | 5 | | | 8 | | | 11 | |
| Total operating revenues | 1,425 | | | 1,517 | | | 3,158 | | | 3,052 | |
| Operating expenses | | | | | | | |
| Purchased power | 283 | | | 421 | | | 862 | | | 862 | |
| Purchased power from affiliate | — | | | 79 | | | 59 | | | 163 | |
| Operating and maintenance | 258 | | | 250 | | | 523 | | | 495 | |
| Operating and maintenance from affiliates | 80 | | | 73 | | | 166 | | | 144 | |
| Depreciation and amortization | 328 | | | 296 | | | 649 | | | 589 | |
| Taxes other than income taxes | 90 | | | 77 | | | 185 | | | 153 | |
| Total operating expenses | 1,039 | | | 1,196 | | | 2,444 | | | 2,406 | |
| Loss on sales of assets | (2) | | | — | | | (2) | | | — | |
| Operating income | 384 | | | 321 | | | 712 | | | 646 | |
| Other income and (deductions) | | | | | | | |
| Interest expense, net | (101) | | | (95) | | | (197) | | | (187) | |
| Interest expense to affiliates | (3) | | | (3) | | | (7) | | | (6) | |
| Other, net | 13 | | | 15 | | | 26 | | | 22 | |
| Total other income and (deductions) | (91) | | | (83) | | | (178) | | | (171) | |
| Income before income taxes | 293 | | | 238 | | | 534 | | | 475 | |
| Income taxes | 66 | | | 46 | | | 119 | | | 85 | |
| Net income | $ | 227 | | | $ | 192 | | | $ | 415 | | | $ | 390 | |
| Comprehensive income | $ | 227 | | | $ | 192 | | | $ | 415 | | | $ | 390 | |
See the Combined Notes to Consolidated Financial Statements
15
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
| | | | | | | | | | | |
| Six Months Ended
June 30, |
| (In millions) | 2022 | | 2021 |
| Cash flows from operating activities | | | |
| Net income | $ | 415 | | | $ | 390 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 649 | | | 589 | |
| | | |
| Deferred income taxes and amortization of investment tax credits | 122 | | | 143 | |
| | | |
| Other non-cash operating activities | (18) | | | 23 | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | (163) | | | (48) | |
| Receivables from and payables to affiliates, net | (43) | | | 5 | |
| Inventories | (2) | | | (2) | |
| Accounts payable and accrued expenses | 123 | | | (45) | |
| Collateral received, net | 60 | | | 2 | |
| Income taxes | (19) | | | (34) | |
| Regulatory assets and liabilities, net | (267) | | | (181) | |
| Pension and non-pension postretirement benefit contributions | (178) | | | (173) | |
| Other assets and liabilities | (91) | | | (111) | |
| Net cash flows provided by operating activities | 588 | | | 558 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (1,208) | | | (1,162) | |
| | | |
| | | |
| | | |
| | | |
| Other investing activities | 15 | | | 12 | |
| Net cash flows used in investing activities | (1,193) | | | (1,150) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | — | | | (290) | |
| Issuance of long-term debt | 750 | | | 700 | |
| | | |
| | | |
| Dividends paid on common stock | (289) | | | (253) | |
| Contributions from parent | 335 | | | 395 | |
| | | |
| | | |
| Other financing activities | (12) | | | (11) | |
| Net cash flows provided by financing activities | 784 | | | 541 | |
| Increase (decrease) in cash, restricted cash, and cash equivalents | 179 | | | (51) | |
| Cash, restricted cash, and cash equivalents at beginning of period | 384 | | | 405 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 563 | | | $ | 354 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (44) | | | $ | (93) | |
| | | |
| | | |
See the Combined Notes to Consolidated Financial Statements
16
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
| | | | | | | | | | | | | | | |
| | | Three Months Ended
March 31, |
| (In millions) | | | | | 2023 | | 2022 |
| Operating revenues | | | | | | | |
| Electric operating revenues | | | | | $ | 1,511 | | | $ | 1,688 | |
| Revenues from alternative revenue programs | | | | | 153 | | | 40 | |
| Operating revenues from affiliates | | | | | 3 | | | 6 | |
| Total operating revenues | | | | | 1,667 | | | 1,734 | |
| Operating expenses | | | | | | | |
| Purchased power | | | | | 488 | | | 579 | |
| Purchased power from affiliate | | | | | — | | | 59 | |
| Operating and maintenance | | | | | 254 | | | 266 | |
| Operating and maintenance from affiliates | | | | | 83 | | | 85 | |
| Depreciation and amortization | | | | | 338 | | | 321 | |
| Taxes other than income taxes | | | | | 93 | | | 96 | |
| Total operating expenses | | | | | 1,256 | | | 1,406 | |
| | | | | | | |
| Operating income | | | | | 411 | | | 328 | |
| Other income and (deductions) | | | | | | | |
| Interest expense, net | | | | | (114) | | | (97) | |
| Interest expense to affiliates | | | | | (3) | | | (3) | |
| Other, net | | | | | 18 | | | 12 | |
| Total other income and (deductions) | | | | | (99) | | | (88) | |
| Income before income taxes | | | | | 312 | | | 240 | |
| Income taxes | | | | | 71 | | | 52 | |
| Net income | | | | | $ | 241 | | | $ | 188 | |
| Comprehensive income | | | | | $ | 241 | | | $ | 188 | |
See the Combined Notes to Consolidated Financial Statements
14
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
| | | | | | | | | | | |
| Three Months Ended
March 31, |
| (In millions) | 2023 | | 2022 |
| Cash flows from operating activities | | | |
| Net income | $ | 241 | | | $ | 188 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 338 | | | 321 | |
| | | |
| Deferred income taxes and amortization of investment tax credits | 55 | | | 54 | |
| | | |
| Other non-cash operating activities | (153) | | | (9) | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | 96 | | | (45) | |
| Receivables from and payables to affiliates, net | 10 | | | (42) | |
| Inventories | (21) | | | 3 | |
| Accounts payable and accrued expenses | (306) | | | (154) | |
| Collateral (paid) received, net | (4) | | | 43 | |
| Income taxes | 15 | | | (2) | |
| Regulatory assets and liabilities, net | (338) | | | (8) | |
| Pension and non-pension postretirement benefit contributions | (23) | | | (176) | |
| Other assets and liabilities | (22) | | | (29) | |
| Net cash flows (used in) provided by operating activities | (112) | | | 144 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (617) | | | (617) | |
| | | |
| | | |
| | | |
| | | |
| Other investing activities | 1 | | | 7 | |
| Net cash flows used in investing activities | (616) | | | (610) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | (18) | | | — | |
| Repayments on short-term borrowings with maturities greater than 90 days | (150) | | | — | |
| Issuance of long-term debt | 975 | | | 750 | |
| | | |
| Dividends paid on common stock | (187) | | | (144) | |
| Contributions from parent | 186 | | | 167 | |
| | | |
| Other financing activities | (11) | | | (10) | |
| Net cash flows provided by financing activities | 795 | | | 763 | |
| Increase in cash, restricted cash, and cash equivalents | 67 | | | 297 | |
| Cash, restricted cash, and cash equivalents at beginning of period | 511 | | | 384 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 578 | | | $ | 681 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (35) | | | $ | (50) | |
| | | |
| | | |
See the Combined Notes to Consolidated Financial Statements
15
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | (In millions) | (In millions) | June 30, 2022 | | December 31, 2021 | (In millions) | March 31, 2023 | | December 31, 2022 |
| ASSETS | ASSETS | | | | ASSETS | | | |
| Current assets | Current assets | | Current assets | |
| Cash and cash equivalents | Cash and cash equivalents | $ | 120 | | | $ | 131 | | Cash and cash equivalents | $ | 75 | | | $ | 67 | |
| Restricted cash and cash equivalents | Restricted cash and cash equivalents | 384 | | | 210 | | Restricted cash and cash equivalents | 323 | | | 327 | |
| Accounts receivable | Accounts receivable | | Accounts receivable | |
| Customer accounts receivable | Customer accounts receivable | 589 | | 647 | Customer accounts receivable | 674 | | 558 |
| Customer allowance for credit losses | Customer allowance for credit losses | (81) | | (73) | Customer allowance for credit losses | (74) | | (59) |
| Customer accounts receivable, net | Customer accounts receivable, net | 508 | | | 574 | | Customer accounts receivable, net | 600 | | | 499 | |
| Other accounts receivable | Other accounts receivable | 448 | | 227 | Other accounts receivable | 233 | | 441 |
| Other allowance for credit losses | Other allowance for credit losses | (18) | | (17) | Other allowance for credit losses | (18) | | (17) |
| Other accounts receivable, net | Other accounts receivable, net | 430 | | | 210 | | Other accounts receivable, net | 215 | | | 424 | |
| | Receivables from affiliates | Receivables from affiliates | 3 | | | 16 | | Receivables from affiliates | 3 | | | 3 | |
| | Inventories, net | Inventories, net | 171 | | | 170 | | Inventories, net | 216 | | | 196 | |
| | Regulatory assets | Regulatory assets | 325 | | | 335 | | Regulatory assets | 1,472 | | | 775 | |
| | Other | Other | 143 | | | 76 | | Other | 102 | | | 92 | |
| Total current assets | Total current assets | 2,084 | | | 1,722 | | Total current assets | 3,006 | | | 2,383 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $6,400 and $6,099 as of June 30, 2022 and December 31, 2021, respectively) | 26,673 | | | 25,995 | | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $6,838 and $6,673 as of March 31, 2023 and December 31, 2022, respectively) | | Property, plant, and equipment (net of accumulated depreciation and amortization of $6,838 and $6,673 as of March 31, 2023 and December 31, 2022, respectively) | 27,858 | | | 27,513 | |
| Deferred debits and other assets | Deferred debits and other assets | | Deferred debits and other assets | |
| Regulatory assets | Regulatory assets | 2,134 | | | 1,870 | | Regulatory assets | 2,517 | | | 2,667 | |
| | Goodwill | Goodwill | 2,625 | | | 2,625 | | Goodwill | 2,625 | | | 2,625 | |
| Receivables from affiliates | — | | | 2,761 | | |
| | Receivable related to Regulatory Agreement Units | Receivable related to Regulatory Agreement Units | 1,973 | | | — | | Receivable related to Regulatory Agreement Units | 2,804 | | | 2,660 | |
| Investments | Investments | 6 | | | 6 | | Investments | 6 | | | 6 | |
| Prepaid pension asset | Prepaid pension asset | 1,232 | | | 1,086 | | Prepaid pension asset | 1,225 | | | 1,206 | |
| | Other | Other | 467 | | | 405 | | Other | 679 | | | 601 | |
| Total deferred debits and other assets | Total deferred debits and other assets | 8,437 | | | 8,753 | | Total deferred debits and other assets | 9,856 | | | 9,765 | |
| Total assets | Total assets | $ | 37,194 | | | $ | 36,470 | | Total assets | $ | 40,720 | | | $ | 39,661 | |
See the Combined Notes to Consolidated Financial Statements
1716
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | (In millions) | (In millions) | June 30, 2022 | | December 31, 2021 | (In millions) | March 31, 2023 | | December 31, 2022 |
| LIABILITIES AND SHAREHOLDERS’ EQUITY | LIABILITIES AND SHAREHOLDERS’ EQUITY | | | | LIABILITIES AND SHAREHOLDERS’ EQUITY | | | |
| Current liabilities | Current liabilities | | Current liabilities | |
| | Short-term borrowings | | Short-term borrowings | $ | 409 | | | $ | 577 | |
| | Accounts payable | Accounts payable | $ | 756 | | | $ | 647 | | Accounts payable | 801 | | | 1,010 | |
| Accrued expenses | Accrued expenses | 345 | | | 384 | | Accrued expenses | 305 | | | 415 | |
| Payables to affiliates | Payables to affiliates | 65 | | | 121 | | Payables to affiliates | 84 | | | 74 | |
| | Customer deposits | Customer deposits | 99 | | | 99 | | Customer deposits | 109 | | | 108 | |
| Regulatory liabilities | Regulatory liabilities | 216 | | | 185 | | Regulatory liabilities | 233 | | | 226 | |
| Mark-to-market derivative liabilities | Mark-to-market derivative liabilities | — | | | 18 | | Mark-to-market derivative liabilities | 22 | | | 5 | |
| | Other | Other | 253 | | | 133 | | Other | 189 | | | 191 | |
| Total current liabilities | Total current liabilities | 1,734 | | | 1,587 | | Total current liabilities | 2,152 | | | 2,606 | |
| Long-term debt | Long-term debt | 10,516 | | | 9,773 | | Long-term debt | 11,480 | | | 10,518 | |
| Long-term debt to financing trust | Long-term debt to financing trust | 205 | | | 205 | | Long-term debt to financing trust | 205 | | | 205 | |
| Deferred credits and other liabilities | Deferred credits and other liabilities | | Deferred credits and other liabilities | |
| Deferred income taxes and unamortized investment tax credits | Deferred income taxes and unamortized investment tax credits | 4,852 | | | 4,685 | | Deferred income taxes and unamortized investment tax credits | 5,100 | | | 5,021 | |
| Regulatory liabilities | Regulatory liabilities | 6,111 | | | 6,759 | | Regulatory liabilities | 7,143 | | | 6,913 | |
| Asset retirement obligations | Asset retirement obligations | 145 | | | 144 | | Asset retirement obligations | 149 | | | 148 | |
| | Non-pension postretirement benefits obligations | Non-pension postretirement benefits obligations | 168 | | | 169 | | Non-pension postretirement benefits obligations | 167 | | | 165 | |
| | Mark-to-market derivative liabilities | Mark-to-market derivative liabilities | 103 | | | 201 | | Mark-to-market derivative liabilities | 76 | | | 79 | |
| | Other | Other | 544 | | | 592 | | Other | 644 | | | 642 | |
| Total deferred credits and other liabilities | Total deferred credits and other liabilities | 11,923 | | | 12,550 | | Total deferred credits and other liabilities | 13,279 | | | 12,968 | |
| Total liabilities | Total liabilities | 24,378 | | | 24,115 | | Total liabilities | 27,116 | | | 26,297 | |
| Commitments and contingencies | Commitments and contingencies | 0 | | 0 | Commitments and contingencies | | | |
| Shareholders’ equity | Shareholders’ equity | | Shareholders’ equity | |
| Common stock | Common stock | 1,588 | | | 1,588 | | Common stock | 1,588 | | | 1,588 | |
| | Other paid-in capital | Other paid-in capital | 9,411 | | | 9,076 | | Other paid-in capital | 9,932 | | | 9,746 | |
| Retained earnings | Retained earnings | 1,817 | | | 1,691 | | Retained earnings | 2,084 | | | 2,030 | |
| | Total shareholders’ equity | Total shareholders’ equity | 12,816 | | | 12,355 | | Total shareholders’ equity | 13,604 | | | 13,364 | |
| Total liabilities and shareholders’ equity | Total liabilities and shareholders’ equity | $ | 37,194 | | | $ | 36,470 | | Total liabilities and shareholders’ equity | $ | 40,720 | | | $ | 39,661 | |
See the Combined Notes to Consolidated Financial Statements
1817
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY
(Unaudited)
| | | | Three Months Ended March 31, 2023 |
| (In millions) | | (In millions) | Common
Stock | | Other
Paid-In
Capital | | Retained
Earnings | | Total
Shareholders’
Equity |
| Balance, December 31, 2022 | | Balance, December 31, 2022 | $ | 1,588 | | | $ | 9,746 | | | $ | 2,030 | | | $ | 13,364 | |
| Net income | | Net income | — | | | — | | | 241 | | | 241 | |
| Common stock dividends | | Common stock dividends | — | | | — | | | (187) | | | (187) | |
| Contributions from parent | | Contributions from parent | — | | | 186 | | | — | | | 186 | |
| Balance, March 31, 2023 | | Balance, March 31, 2023 | $ | 1,588 | | | $ | 9,932 | | | $ | 2,084 | | | $ | 13,604 | |
| | | | Six Months Ended June 30, 2022 | | Three Months Ended March 31, 2022 |
| (In millions) | (In millions) | Common
Stock | | Other
Paid-In
Capital | | Retained
Earnings | | Total
Shareholders’
Equity | (In millions) | Common
Stock | | Other
Paid-In
Capital | | Retained
Earnings | | Total
Shareholders’
Equity |
| Balance, December 31, 2021 | Balance, December 31, 2021 | $ | 1,588 | | | $ | 9,076 | | | $ | 1,691 | | | $ | 12,355 | | Balance, December 31, 2021 | $ | 1,588 | | | $ | 9,076 | | | $ | 1,691 | | | $ | 12,355 | |
| Net income | Net income | — | | | — | | | 188 | | | 188 | | Net income | — | | | — | | | 188 | | | 188 | |
| Common stock dividends | Common stock dividends | — | | | — | | | (144) | | | (144) | | Common stock dividends | — | | | — | | | (144) | | | (144) | |
| Contributions from parent | Contributions from parent | — | | | 167 | | | — | | | 167 | | Contributions from parent | — | | | 167 | | | — | | | 167 | |
| Balance, March 31, 2022 | Balance, March 31, 2022 | $ | 1,588 | | | $ | 9,243 | | | $ | 1,735 | | | $ | 12,566 | | Balance, March 31, 2022 | $ | 1,588 | | | $ | 9,243 | | | $ | 1,735 | | | $ | 12,566 | |
| Net income | — | | | — | | | 227 | | | 227 | | |
| Common stock dividends | — | | | — | | | (145) | | | (145) | | |
| Contributions from parent | — | | | 168 | | | — | | | 168 | | |
| Balance, June 30, 2022 | $ | 1,588 | | | $ | 9,411 | | | $ | 1,817 | | | $ | 12,816 | | |
| | | | Six Months Ended June 30, 2021 | |
| (In millions) | Common
Stock | | Other
Paid-In
Capital | | Retained
Earnings | | Total
Shareholders’
Equity | |
| Balance, December 31, 2020 | $ | 1,588 | | | $ | 8,285 | | | $ | 1,456 | | | $ | 11,329 | | |
| Net income | — | | | — | | | 197 | | | 197 | | |
| Common stock dividends | — | | | — | | | (127) | | | (127) | | |
| Contributions from parent | — | | | 198 | | | — | | | 198 | | |
| Balance, March 31, 2021 | $ | 1,588 | | | $ | 8,483 | | | $ | 1,526 | | | $ | 11,597 | | |
| Net income | — | | | — | | | 192 | | | 192 | | |
| Common stock dividends | — | | | — | | | (126) | | | (126) | | |
| Contributions from parent | — | | | 197 | | | — | | | 197 | | |
| Balance, June 30, 2021 | $ | 1,588 | | | $ | 8,680 | | | $ | 1,592 | | | $ | 11,860 | | |
|
See the Combined Notes to Consolidated Financial Statements
1918
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
| | | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | | Three Months Ended
March 31, |
| (In millions) | (In millions) | 2022 | | 2021 | | 2022 | | 2021 | (In millions) | | 2023 | | 2022 |
| Operating revenues | Operating revenues | | | | | | | | Operating revenues | | | | |
| Electric operating revenues | Electric operating revenues | $ | 707 | | | $ | 602 | | | $ | 1,441 | | | $ | 1,251 | | Electric operating revenues | | $ | 798 | | | $ | 734 | |
| Natural gas operating revenues | Natural gas operating revenues | 108 | | | 82 | | | 414 | | | 310 | | Natural gas operating revenues | | 316 | | | 306 | |
| Revenues from alternative revenue programs | Revenues from alternative revenue programs | — | | | 7 | | | 6 | | | 17 | | Revenues from alternative revenue programs | | (4) | | | 6 | |
| Operating revenues from affiliates | Operating revenues from affiliates | 1 | | | 2 | | | 2 | | | 4 | | Operating revenues from affiliates | | 2 | | | 1 | |
| Total operating revenues | Total operating revenues | 816 | | | 693 | | | 1,863 | | | 1,582 | | Total operating revenues | | 1,112 | | | 1,047 | |
| Operating expenses | Operating expenses | | | | | | | | Operating expenses | | | | |
| Purchased power | Purchased power | 244 | | | 145 | | | 472 | | | 334 | | Purchased power | | 330 | | | 229 | |
| Purchased fuel | Purchased fuel | 39 | | | 22 | | | 184 | | | 108 | | Purchased fuel | | 154 | | | 145 | |
| Purchased power from affiliate | Purchased power from affiliate | — | | | 40 | | | 33 | | | 81 | | Purchased power from affiliate | | — | | | 33 | |
| Operating and maintenance | Operating and maintenance | 168 | | | 166 | | | 364 | | | 360 | | Operating and maintenance | | 219 | | | 196 | |
| Operating and maintenance from affiliates | Operating and maintenance from affiliates | 47 | | | 43 | | | 99 | | | 83 | | Operating and maintenance from affiliates | | 51 | | | 51 | |
| Depreciation and amortization | Depreciation and amortization | 93 | | | 87 | | | 185 | | | 173 | | Depreciation and amortization | | 98 | | | 92 | |
| Taxes other than income taxes | Taxes other than income taxes | 48 | | | 49 | | | 95 | | | 92 | | Taxes other than income taxes | | 50 | | | 47 | |
| Total operating expenses | Total operating expenses | 639 | | | 552 | | | 1,432 | | | 1,231 | | Total operating expenses | | 902 | | | 793 | |
| | Operating income | Operating income | 177 | | | 141 | | | 431 | | | 351 | | Operating income | | 210 | | | 254 | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | Other income and (deductions) | | | | |
| Interest expense, net | Interest expense, net | (40) | | | (39) | | | (78) | | | (74) | | Interest expense, net | | (45) | | | (38) | |
| Interest expense to affiliates | Interest expense to affiliates | (3) | | | (3) | | | (6) | | | (6) | | Interest expense to affiliates | | (3) | | | (3) | |
| Other, net | Other, net | 8 | | | 7 | | | 16 | | | 12 | | Other, net | | 8 | | | 7 | |
| Total other income and (deductions) | Total other income and (deductions) | (35) | | | (35) | | | (68) | | | (68) | | Total other income and (deductions) | | (40) | | | (34) | |
| Income before income taxes | Income before income taxes | 142 | | | 106 | | | 363 | | | 283 | | Income before income taxes | | 170 | | | 220 | |
| Income taxes | Income taxes | 9 | | | 2 | | | 24 | | | 12 | | Income taxes | | 4 | | | 14 | |
| | Net income | Net income | $ | 133 | | | $ | 104 | | | $ | 339 | | | $ | 271 | | Net income | | $ | 166 | | | $ | 206 | |
| Comprehensive income | Comprehensive income | $ | 133 | | | $ | 104 | | | $ | 339 | | | $ | 271 | | Comprehensive income | | $ | 166 | | | $ | 206 | |
See the Combined Notes to Consolidated Financial Statements
19
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
| | | | | | | | | | | |
| Three Months Ended
March 31, |
| (In millions) | 2023 | | 2022 |
| Cash flows from operating activities | | | |
| Net income | $ | 166 | | | $ | 206 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 98 | | | 92 | |
| | | |
| | | |
| Deferred income taxes and amortization of investment tax credits | (16) | | | 14 | |
| Other non-cash operating activities | 32 | | | 15 | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | 36 | | | (40) | |
| Receivables from and payables to affiliates, net | 8 | | | (31) | |
| Inventories | 60 | | | 27 | |
| Accounts payable and accrued expenses | (176) | | | (24) | |
| | | |
| Income taxes | 20 | | | — | |
| Regulatory assets and liabilities, net | 15 | | | (4) | |
| Pension and non-pension postretirement benefit contributions | — | | | (12) | |
| Other assets and liabilities | (75) | | | (102) | |
| Net cash flows provided by operating activities | 168 | | | 141 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (335) | | | (344) | |
| | | |
| | | |
| Other investing activities | — | | | 2 | |
| Net cash flows used in investing activities | (335) | | | (342) | |
| Cash flows from financing activities | | | |
| | | |
| Changes in short-term borrowings | (94) | | | — | |
| | | |
| | | |
| | | |
| Changes in Exelon intercompany money pool | — | | | 65 | |
| Dividends paid on common stock | (101) | | | (100) | |
| Contributions from parent | 330 | | | 227 | |
| | | |
| | | |
| Other financing activities | — | | | (1) | |
| Net cash flows provided by financing activities | 135 | | | 191 | |
| Decrease in cash, restricted cash, and cash equivalents | (32) | | | (10) | |
| Cash, restricted cash, and cash equivalents at beginning of period | 68 | | | 44 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 36 | | | $ | 34 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (9) | | | $ | (41) | |
| | | |
See the Combined Notes to Consolidated Financial Statements
20
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWSBALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| Six Months Ended
June 30, |
| (In millions) | 2022 | | 2021 |
| Cash flows from operating activities | | | |
| Net income | $ | 339 | | | $ | 271 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 185 | | | 173 | |
| | | |
| | | |
| Deferred income taxes and amortization of investment tax credits | 14 | | | 21 | |
| Other non-cash operating activities | 4 | | | (5) | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | (29) | | | 86 | |
| Receivables from and payables to affiliates, net | (40) | | | 2 | |
| Inventories | (8) | | | 3 | |
| Accounts payable and accrued expenses | 5 | | | (46) | |
| | | |
| Income taxes | 49 | | | 24 | |
| Regulatory assets and liabilities, net | (24) | | | (14) | |
| Pension and non-pension postretirement benefit contributions | (13) | | | (15) | |
| Other assets and liabilities | (70) | | | (126) | |
| Net cash flows provided by operating activities | 412 | | | 374 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (658) | | | (577) | |
| | | |
| | | |
| Other investing activities | 5 | | | 4 | |
| Net cash flows used in investing activities | (653) | | | (573) | |
| Cash flows from financing activities | | | |
| | | |
| Changes in short-term borrowings | 210 | | | — | |
| Issuance of long-term debt | 350 | | | 375 | |
| Retirement of long-term debt | (350) | | | — | |
| | | |
| Changes in Exelon intercompany money pool | — | | | (40) | |
| Dividends paid on common stock | (200) | | | (169) | |
| Contributions from parent | 227 | | | 395 | |
| | | |
| | | |
| Other financing activities | (8) | | | (4) | |
| Net cash flows provided by financing activities | 229 | | | 557 | |
| (Decrease) increase in cash, restricted cash, and cash equivalents | (12) | | | 358 | |
| Cash, restricted cash, and cash equivalents at beginning of period | 44 | | | 26 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 32 | | | $ | 384 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (11) | | | $ | (16) | |
| | | |
| | | | | | | | | | | |
| (In millions) | March 31, 2023 | | December 31, 2022 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 27 | | | $ | 59 | |
| Restricted cash and cash equivalents | 9 | | | 9 | |
| Accounts receivable | | | |
| Customer accounts receivable | 588 | | 635 |
| Customer allowance for credit losses | (130) | | (105) |
| Customer accounts receivable, net | 458 | | | 530 | |
| Other accounts receivable | 147 | | 153 |
| Other allowance for credit losses | (11) | | (9) |
| Other accounts receivable, net | 136 | | | 144 | |
| | | |
| Receivables from affiliates | 2 | | | 4 | |
| | | |
| | | |
| Inventories, net | | | |
| Fossil fuel | 41 | | | 99 | |
| Materials and supplies | 50 | | | 52 | |
| Prepaid utility taxes | 100 | | | — | |
| Regulatory assets | 83 | | | 80 | |
| | | |
| Other | 43 | | | 38 | |
| Total current assets | 949 | | | 1,015 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $4,135 and $4,078 as of March 31, 2023 and December 31, 2022, respectively) | 12,359 | | | 12,125 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 693 | | | 652 | |
| | | |
| | | |
| | | |
| | | |
| Receivable related to Regulatory Agreement Units | 265 | | | 237 | |
| Investments | 31 | | | 30 | |
| Prepaid pension asset | 417 | | | 413 | |
| | | |
| Other | 24 | | | 30 | |
| Total deferred debits and other assets | 1,430 | | | 1,362 | |
| Total assets | $ | 14,738 | | | $ | 14,502 | |
See the Combined Notes to Consolidated Financial Statements
21
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| (In millions) | June 30, 2022 | | December 31, 2021 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 23 | | | $ | 36 | |
| Restricted cash and cash equivalents | 9 | | | 8 | |
| Accounts receivable | | | |
| Customer accounts receivable | 493 | | 489 |
| Customer allowance for credit losses | (107) | | (105) |
| Customer accounts receivable, net | 386 | | | 384 | |
| Other accounts receivable | 138 | | 116 |
| Other allowance for credit losses | (10) | | (7) |
| Other accounts receivable, net | 128 | | | 109 | |
| | | |
| Receivables from affiliates | — | | | 1 | |
| | | |
| | | |
| Inventories, net | | | |
| Fossil fuel | 55 | | | 51 | |
| Materials and supplies | 48 | | | 45 | |
| Prepaid utility taxes | 85 | | | 1 | |
| Regulatory assets | 61 | | | 48 | |
| | | |
| Other | 36 | | | 28 | |
| Total current assets | 831 | | | 711 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $4,021 and $3,964 as of June 30, 2022 and December 31, 2021, respectively) | 11,591 | | | 11,117 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 1,033 | | | 943 | |
| | | |
| | | |
| | | |
| Receivables from affiliates | — | | | 597 | |
| Receivable related to Regulatory Agreement Units | 292 | | | — | |
| Investments | 32 | | | 34 | |
| Prepaid pension asset | 405 | | | 386 | |
| | | |
| | | |
| Other | 32 | | | 36 | |
| Total deferred debits and other assets | 1,794 | | | 1,996 | |
| Total assets | $ | 14,216 | | | $ | 13,824 | |
See the Combined Notes to Consolidated Financial Statements
22
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | (In millions) | (In millions) | June 30, 2022 | | December 31, 2021 | (In millions) | March 31, 2023 | | December 31, 2022 |
| LIABILITIES AND SHAREHOLDER'S EQUITY | LIABILITIES AND SHAREHOLDER'S EQUITY | | | | LIABILITIES AND SHAREHOLDER'S EQUITY | | | |
| Current liabilities | Current liabilities | | Current liabilities | |
| Short-term borrowings | Short-term borrowings | $ | 210 | | | $ | — | | Short-term borrowings | $ | 145 | | | $ | 239 | |
| Long-term debt due within one year | Long-term debt due within one year | 50 | | | 350 | | Long-term debt due within one year | 50 | | | 50 | |
| Accounts payable | Accounts payable | 525 | | | 494 | | Accounts payable | 543 | | | 668 | |
| Accrued expenses | Accrued expenses | 161 | | | 136 | | Accrued expenses | 95 | | | 142 | |
| Payables to affiliates | Payables to affiliates | 29 | | | 70 | | Payables to affiliates | 48 | | | 42 | |
| | Customer deposits | Customer deposits | 53 | | | 48 | | Customer deposits | 66 | | | 63 | |
| Regulatory liabilities | Regulatory liabilities | 75 | | | 94 | | Regulatory liabilities | 95 | | | 75 | |
| | Other | Other | 47 | | | 35 | | Other | 50 | | | 32 | |
| Total current liabilities | Total current liabilities | 1,150 | | | 1,227 | | Total current liabilities | 1,092 | | | 1,311 | |
| Long-term debt | Long-term debt | 4,142 | | | 3,847 | | Long-term debt | 4,563 | | | 4,562 | |
| Long-term debt to financing trusts | Long-term debt to financing trusts | 184 | | | 184 | | Long-term debt to financing trusts | 184 | | | 184 | |
| Deferred credits and other liabilities | Deferred credits and other liabilities | | Deferred credits and other liabilities | |
| Deferred income taxes and unamortized investment tax credits | Deferred income taxes and unamortized investment tax credits | 2,534 | | | 2,421 | | Deferred income taxes and unamortized investment tax credits | 2,245 | | | 2,213 | |
| Regulatory liabilities | Regulatory liabilities | 329 | | | 635 | | Regulatory liabilities | 295 | | | 270 | |
| Asset retirement obligations | Asset retirement obligations | 29 | | | 29 | | Asset retirement obligations | 28 | | | 28 | |
| Non-pension postretirement benefits obligations | Non-pension postretirement benefits obligations | 288 | | | 286 | | Non-pension postretirement benefits obligations | 286 | | | 286 | |
| | Other | Other | 82 | | | 83 | | Other | 87 | | | 85 | |
| Total deferred credits and other liabilities | Total deferred credits and other liabilities | 3,262 | | | 3,454 | | Total deferred credits and other liabilities | 2,941 | | | 2,882 | |
| Total liabilities | Total liabilities | 8,738 | | | 8,712 | | Total liabilities | 8,780 | | | 8,939 | |
| Commitments and contingencies | Commitments and contingencies | 0 | | 0 | Commitments and contingencies | | | |
| Shareholder’s equity | Shareholder’s equity | | Shareholder’s equity | |
| Common stock | Common stock | 3,655 | | | 3,428 | | Common stock | 4,032 | | | 3,702 | |
| | Retained earnings | Retained earnings | 1,823 | | | 1,684 | | Retained earnings | 1,926 | | | 1,861 | |
| | Total shareholder’s equity | Total shareholder’s equity | 5,478 | | | 5,112 | | Total shareholder’s equity | 5,958 | | | 5,563 | |
| Total liabilities and shareholder's equity | Total liabilities and shareholder's equity | $ | 14,216 | | | $ | 13,824 | | Total liabilities and shareholder's equity | $ | 14,738 | | | $ | 14,502 | |
See the Combined Notes to Consolidated Financial Statements
2322
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY
(Unaudited)
| | | | Three Months Ended March 31, 2023 |
| (In millions) | | (In millions) | Common
Stock | | Retained
Earnings | | | Total
Shareholder's
Equity |
| Balance, December 31, 2022 | | Balance, December 31, 2022 | $ | 3,702 | | | $ | 1,861 | | | | $ | 5,563 | |
| Net income | | Net income | — | | | 166 | | | | 166 | |
| Common stock dividends | | Common stock dividends | — | | | (101) | | | | (101) | |
| Contributions from parent | | Contributions from parent | 330 | | | — | | | | 330 | |
| Balance, March 31, 2023 | | Balance, March 31, 2023 | $ | 4,032 | | | $ | 1,926 | | | | $ | 5,958 | |
| | | | Six Months Ended June 30, 2022 | | Three Months Ended March 31, 2022 |
| (In millions) | (In millions) | Common
Stock | | Retained
Earnings | | | Total
Shareholder's
Equity | (In millions) | Common
Stock | | Retained
Earnings | | | Total
Shareholder's
Equity |
| Balance, December 31, 2021 | Balance, December 31, 2021 | $ | 3,428 | | | $ | 1,684 | | | | $ | 5,112 | | Balance, December 31, 2021 | $ | 3,428 | | | $ | 1,684 | | | | $ | 5,112 | |
| Net income | Net income | — | | | 206 | | | | 206 | | Net income | — | | | 206 | | | | 206 | |
| Common stock dividends | Common stock dividends | — | | | (100) | | | | (100) | | Common stock dividends | — | | | (100) | | | | (100) | |
| Contributions from parent | Contributions from parent | 227 | | | — | | | | 227 | | Contributions from parent | 227 | | | — | | | | 227 | |
| Balance, March 31, 2022 | Balance, March 31, 2022 | $ | 3,655 | | | $ | 1,790 | | | | $ | 5,445 | | Balance, March 31, 2022 | $ | 3,655 | | | $ | 1,790 | | | | $ | 5,445 | |
| Net income | — | | | 133 | | | | 133 | | |
| Common stock dividends | — | | | (100) | | | | (100) | | |
| | Balance, June 30, 2022 | $ | 3,655 | | | $ | 1,823 | | | | $ | 5,478 | | |
| | | | Six Months Ended June 30, 2021 | |
| (In millions) | Common
Stock | | Retained
Earnings | | | Total
Shareholder's
Equity | |
| Balance, December 31, 2020 | $ | 3,014 | | | $ | 1,519 | | | | $ | 4,533 | | |
| Net income | — | | | 167 | | | | 167 | | |
| Common stock dividends | — | | | (85) | | | | (85) | | |
| | Balance, March 31, 2021 | $ | 3,014 | | | $ | 1,601 | | | | $ | 4,615 | | |
| Net income | — | | | 104 | | | | 104 | | |
| Common stock dividends | — | | | (84) | | | | (84) | | |
| Contributions from parent | 395 | | | — | | | | 395 | | |
| Balance, June 30, 2021 | $ | 3,409 | | | $ | 1,621 | | | | $ | 5,030 | | |
|
See the Combined Notes to Consolidated Financial Statements
2423
BALTIMORE GAS AND ELECTRIC COMPANY
STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | | Three Months Ended
March 31, |
| (In millions) | (In millions) | 2022 | | 2021 | | 2022 | | 2021 | (In millions) | | 2023 | | 2022 |
| Operating revenues | Operating revenues | | | | | | | | Operating revenues | | | | |
| Electric operating revenues | Electric operating revenues | $ | 642 | | | $ | 560 | | | $ | 1,377 | | | $ | 1,180 | | Electric operating revenues | | $ | 780 | | | $ | 735 | |
| Natural gas operating revenues | Natural gas operating revenues | 161 | | | 125 | | | 585 | | | 455 | | Natural gas operating revenues | | 409 | | | 424 | |
| Revenues from alternative revenue programs | Revenues from alternative revenue programs | (20) | | | (10) | | | (32) | | | 8 | | Revenues from alternative revenue programs | | 65 | | | (12) | |
| Operating revenues from affiliates | Operating revenues from affiliates | 3 | | | 7 | | | 10 | | | 13 | | Operating revenues from affiliates | | 3 | | | 7 | |
| Total operating revenues | Total operating revenues | 786 | | | 682 | | | 1,940 | | | 1,656 | | Total operating revenues | | 1,257 | | | 1,154 | |
| Operating expenses | Operating expenses | | | | | | | | Operating expenses | | | | |
| Purchased power | Purchased power | 241 | | | 133 | | | 526 | | | 295 | | Purchased power | | 343 | | | 285 | |
| Purchased fuel | Purchased fuel | 48 | | | 27 | | | 199 | | | 126 | | Purchased fuel | | 149 | | | 151 | |
| Purchased power and fuel from affiliate | — | | | 59 | | | 18 | | | 129 | | |
| Purchased power from affiliate | | Purchased power from affiliate | | — | | | 18 | |
| Operating and maintenance | Operating and maintenance | 154 | | | 147 | | | 321 | | | 299 | | Operating and maintenance | | 168 | | | 167 | |
| Operating and maintenance from affiliates | Operating and maintenance from affiliates | 51 | | | 46 | | | 102 | | | 91 | | Operating and maintenance from affiliates | | 54 | | | 51 | |
| Depreciation and amortization | Depreciation and amortization | 152 | | | 141 | | | 322 | | | 293 | | Depreciation and amortization | | 167 | | | 171 | |
| Taxes other than income taxes | Taxes other than income taxes | 71 | | | 67 | | | 148 | | | 139 | | Taxes other than income taxes | | 83 | | | 76 | |
| Total operating expenses | Total operating expenses | 717 | | | 620 | | | 1,636 | | | 1,372 | | Total operating expenses | | 964 | | | 919 | |
| | Operating income | Operating income | 69 | | | 62 | | | 304 | | | 284 | | Operating income | | 293 | | | 235 | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | Other income and (deductions) | | | | |
| Interest expense, net | Interest expense, net | (36) | | | (34) | | | (71) | | | (67) | | Interest expense, net | | (44) | | | (35) | |
| | Other, net | Other, net | 5 | | | 9 | | | 11 | | | 16 | | Other, net | | 3 | | | 7 | |
| Total other income and (deductions) | Total other income and (deductions) | (31) | | | (25) | | | (60) | | | (51) | | Total other income and (deductions) | | (41) | | | (28) | |
| Income before income taxes | Income before income taxes | 38 | | | 37 | | | 244 | | | 233 | | Income before income taxes | | 252 | | | 207 | |
| Income taxes | Income taxes | 1 | | | (8) | | | 10 | | | (21) | | Income taxes | | 52 | | | 9 | |
| | Net income | Net income | $ | 37 | | | $ | 45 | | | $ | 234 | | | $ | 254 | | Net income | | $ | 200 | | | $ | 198 | |
| | Comprehensive income | Comprehensive income | $ | 37 | | | $ | 45 | | | $ | 234 | | | $ | 254 | | Comprehensive income | | $ | 200 | | | $ | 198 | |
|
See the Combined Notes to Consolidated Financial Statements
24
BALTIMORE GAS AND ELECTRIC COMPANY
STATEMENTS OF CASH FLOWS
(Unaudited)
| | | | | | | | | | | |
| Three Months Ended
March 31, |
| (In millions) | 2023 | | 2022 |
| Cash flows from operating activities | | | |
| Net income | $ | 200 | | | $ | 198 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 167 | | | 171 | |
| | | |
| Deferred income taxes and amortization of investment tax credits | 24 | | | 5 | |
| | | |
| Other non-cash operating activities | (32) | | | 44 | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | 43 | | | (80) | |
| Receivables from and payables to affiliates, net | (3) | | | (2) | |
| Inventories | 62 | | | 32 | |
| Accounts payable and accrued expenses | (96) | | | (30) | |
| Collateral (paid) received, net | (22) | | | 30 | |
| Income taxes | 29 | | | 4 | |
| Regulatory assets and liabilities, net | (31) | | | (8) | |
| Pension and non-pension postretirement benefit contributions | (8) | | | (56) | |
| Other assets and liabilities | (24) | | | (31) | |
| Net cash flows provided by operating activities | 309 | | | 277 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (350) | | | (303) | |
| | | |
| Other investing activities | 3 | | | 3 | |
| Net cash flows used in investing activities | (347) | | | (300) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | (165) | | | 120 | |
| | | |
| | | |
| | | |
| | | |
| Dividends paid on common stock | (80) | | | (76) | |
| Contributions from parent | 237 | | | — | |
| Other financing activities | — | | | (1) | |
| Net cash flows (used in) provided by financing activities | (8) | | | 43 | |
| (Decrease) increase in cash, restricted cash, and cash equivalents | (46) | | | 20 | |
| Cash, restricted cash, and cash equivalents at beginning of period | 67 | | | 55 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 21 | | | $ | 75 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (70) | | | $ | (32) | |
| | | |
| | | |
See the Combined Notes to Consolidated Financial Statements
25
BALTIMORE GAS AND ELECTRIC COMPANY
STATEMENTS OF CASH FLOWSBALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| Six Months Ended
June 30, |
| (In millions) | 2022 | | 2021 |
| Cash flows from operating activities | | | |
| Net income | $ | 234 | | | $ | 254 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 322 | | | 293 | |
| | | |
| Deferred income taxes and amortization of investment tax credits | 13 | | | 11 | |
| | | |
| Other non-cash operating activities | 79 | | | 28 | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | (14) | | | 73 | |
| Receivables from and payables to affiliates, net | (11) | | | (19) | |
| Inventories | (27) | | | (9) | |
| Accounts payable and accrued expenses | (12) | | | (51) | |
| Collateral received, net | 190 | | | 2 | |
| Income taxes | (27) | | | (27) | |
| Regulatory assets and liabilities, net | (36) | | | (61) | |
| Pension and non-pension postretirement benefit contributions | (59) | | | (71) | |
| Other assets and liabilities | 24 | | | (35) | |
| Net cash flows provided by operating activities | 676 | | | 388 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (578) | | | (620) | |
| | | |
| Other investing activities | 7 | | | 10 | |
| Net cash flows used in investing activities | (571) | | | (610) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | (130) | | | — | |
| Issuance of long-term debt | 500 | | | 600 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Dividends paid on common stock | (150) | | | (146) | |
| Contributions from parent | 186 | | | — | |
| Other financing activities | (7) | | | (6) | |
| Net cash flows provided by financing activities | 399 | | | 448 | |
| Increase in cash, restricted cash, and cash equivalents | 504 | | | 226 | |
| Cash, restricted cash, and cash equivalents at beginning of period | 55 | | | 145 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 559 | | | $ | 371 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (21) | | | $ | (71) | |
| | | |
| | | |
| | | | | | | | | | | |
| (In millions) | March 31, 2023 | | December 31, 2022 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 20 | | | $ | 43 | |
| Restricted cash and cash equivalents | 1 | | | 24 | |
| Accounts receivable | | | |
| Customer accounts receivable | 581 | | 617 |
| Customer allowance for credit losses | (73) | | (54) |
| Customer accounts receivable, net | 508 | | | 563 | |
| Other accounts receivable | 128 | | 132 |
| Other allowance for credit losses | (12) | | (10) |
| Other accounts receivable, net | 116 | | | 122 | |
| | | |
| | | |
| | | |
| | | |
| Inventories, net | | | |
| Fossil fuel | 23 | | | 91 | |
| Materials and supplies | 71 | | | 65 | |
| Prepaid utility taxes | 49 | | | 52 | |
| Regulatory assets | 237 | | | 177 | |
| | | |
| Other | 13 | | | 13 | |
| Total current assets | 1,038 | | | 1,150 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $4,658 and $4,583 as of March 31, 2023 and December 31, 2022, respectively) | 11,493 | | | 11,338 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 533 | | | 527 | |
| Investments | 9 | | | 7 | |
| | | |
| | | |
| Prepaid pension asset | 280 | | | 291 | |
| | | |
| Other | 58 | | | 37 | |
| Total deferred debits and other assets | 880 | | | 862 | |
| Total assets | $ | 13,411 | | | $ | 13,350 | |
See the Combined Notes to Consolidated Financial Statements
26
BALTIMORE GAS AND ELECTRIC COMPANY
BALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| (In millions) | June 30, 2022 | | December 31, 2021 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 354 | | | $ | 51 | |
| Restricted cash and cash equivalents | 205 | | | 4 | |
| Accounts receivable | | | |
| Customer accounts receivable | 462 | | 436 |
| Customer allowance for credit losses | (57) | | (38) |
| Customer accounts receivable, net | 405 | | | 398 | |
| Other accounts receivable | 122 | | 124 |
| Other allowance for credit losses | (11) | | (9) |
| Other accounts receivable, net | 111 | | | 115 | |
| | | |
| Receivables from affiliates | — | | | 1 | |
| | | |
| | | |
| | | |
| Inventories, net | | | |
| Fossil fuel | 68 | | | 42 | |
| Materials and supplies | 54 | | | 53 | |
| Prepaid utility taxes | — | | | 49 | |
| Regulatory assets | 178 | | | 215 | |
| | | |
| Other | 10 | | | 8 | |
| Total current assets | 1,385 | | | 936 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $4,464 and $4,299 as of June 30, 2022 and December 31, 2021, respectively) | 10,899 | | | 10,577 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 465 | | | 477 | |
| | | |
| Investments | 7 | | | 14 | |
| | | |
| | | |
| | | |
| Prepaid pension asset | 307 | | | 276 | |
| | | |
| | | |
| Other | 30 | | | 44 | |
| Total deferred debits and other assets | 809 | | | 811 | |
| Total assets | $ | 13,093 | | | $ | 12,324 | |
See the Combined Notes to Consolidated Financial Statements
27
BALTIMORE GAS AND ELECTRIC COMPANY
BALANCE SHEETS
(Unaudited)
| | (In millions) | (In millions) | June 30, 2022 | | December 31, 2021 | (In millions) | March 31, 2023 | | December 31, 2022 |
| LIABILITIES AND SHAREHOLDER'S EQUITY | LIABILITIES AND SHAREHOLDER'S EQUITY | | | | LIABILITIES AND SHAREHOLDER'S EQUITY | | | |
| Current liabilities | Current liabilities | | Current liabilities | |
| Short-term borrowings | Short-term borrowings | $ | — | | | $ | 130 | | Short-term borrowings | $ | 243 | | | $ | 408 | |
| Long-term debt due within one year | Long-term debt due within one year | 250 | | | 250 | | Long-term debt due within one year | 300 | | | 300 | |
| Accounts payable | Accounts payable | 339 | | | 349 | | Accounts payable | 310 | | | 462 | |
| Accrued expenses | Accrued expenses | 133 | | | 176 | | Accrued expenses | 174 | | | 159 | |
| Payables to affiliates | Payables to affiliates | 30 | | | 48 | | Payables to affiliates | 37 | | | 39 | |
| | Customer deposits | Customer deposits | 100 | | | 97 | | Customer deposits | 107 | | | 105 | |
| Regulatory liabilities | Regulatory liabilities | 45 | | | 26 | | Regulatory liabilities | 61 | | | 47 | |
| | Other | Other | 224 | | | 48 | | Other | 34 | | | 55 | |
| Total current liabilities | Total current liabilities | 1,121 | | | 1,124 | | Total current liabilities | 1,266 | | | 1,575 | |
| Long-term debt | Long-term debt | 4,206 | | | 3,711 | | Long-term debt | 3,908 | | | 3,907 | |
| | Deferred credits and other liabilities | Deferred credits and other liabilities | | Deferred credits and other liabilities | |
| Deferred income taxes and unamortized investment tax credits | Deferred income taxes and unamortized investment tax credits | 1,777 | | | 1,686 | | Deferred income taxes and unamortized investment tax credits | 1,878 | | | 1,832 | |
| Regulatory liabilities | Regulatory liabilities | 869 | | | 934 | | Regulatory liabilities | 791 | | | 816 | |
| Asset retirement obligations | Asset retirement obligations | 26 | | | 26 | | Asset retirement obligations | 30 | | | 30 | |
| Non-pension postretirement benefits obligations | Non-pension postretirement benefits obligations | 169 | | | 175 | | Non-pension postretirement benefits obligations | 161 | | | 166 | |
| | Other | Other | 85 | | | 98 | | Other | 84 | | | 88 | |
| Total deferred credits and other liabilities | Total deferred credits and other liabilities | 2,926 | | | 2,919 | | Total deferred credits and other liabilities | 2,944 | | | 2,932 | |
| Total liabilities | Total liabilities | 8,253 | | | 7,754 | | Total liabilities | 8,118 | | | 8,414 | |
| Commitments and contingencies | Commitments and contingencies | 0 | | 0 | Commitments and contingencies | | | |
| Shareholder's equity | Shareholder's equity | | Shareholder's equity | |
| Common stock | Common stock | 2,761 | | | 2,575 | | Common stock | 3,098 | | | 2,861 | |
| | Retained earnings | Retained earnings | 2,079 | | | 1,995 | | Retained earnings | 2,195 | | | 2,075 | |
| | Total shareholder's equity | Total shareholder's equity | 4,840 | | | 4,570 | | Total shareholder's equity | 5,293 | | | 4,936 | |
| | Total liabilities and shareholder's equity | Total liabilities and shareholder's equity | $ | 13,093 | | | $ | 12,324 | | Total liabilities and shareholder's equity | $ | 13,411 | | | $ | 13,350 | |
See the Combined Notes to Consolidated Financial Statements
2827
BALTIMORE GAS AND ELECTRIC COMPANY
STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY
(Unaudited)
| | | | Three Months Ended March 31, 2023 | |
| (In millions) | | (In millions) | Common
Stock | | Retained
Earnings | | Total
Shareholder's
Equity | |
| Balance, December 31, 2022 | | Balance, December 31, 2022 | $ | 2,861 | | | $ | 2,075 | | | $ | 4,936 | | |
| Net income | | Net income | — | | | 200 | | | 200 | | |
| Common stock dividends | | Common stock dividends | — | | | (80) | | | (80) | | |
| Contributions from parent | | Contributions from parent | 237 | | | — | | | 237 | | |
| Balance, March 31, 2023 | | Balance, March 31, 2023 | $ | 3,098 | | | $ | 2,195 | | | $ | 5,293 | | |
| | | | Six Months Ended June 30, 2022 | | | Three Months Ended March 31, 2022 | |
| (In millions) | (In millions) | Common
Stock | | Retained
Earnings | | Total
Shareholder's
Equity | | (In millions) | Common
Stock | | Retained
Earnings | | Total
Shareholder's
Equity | |
| Balance, December 31, 2021 | Balance, December 31, 2021 | $ | 2,575 | | | $ | 1,995 | | | $ | 4,570 | | | Balance, December 31, 2021 | $ | 2,575 | | | $ | 1,995 | | | $ | 4,570 | | |
| Net income | Net income | — | | | 198 | | | 198 | | | Net income | — | | | 198 | | | 198 | | |
| Common stock dividends | Common stock dividends | — | | | (76) | | | (76) | | | Common stock dividends | — | | | (76) | | | (76) | | |
| | Balance, March 31, 2022 | Balance, March 31, 2022 | $ | 2,575 | | | $ | 2,117 | | | $ | 4,692 | | | Balance, March 31, 2022 | $ | 2,575 | | | $ | 2,117 | | | $ | 4,692 | | |
| Net income | — | | | 37 | | | 37 | | | |
| Common stock dividends | — | | | (75) | | | (75) | | | |
| Contributions from parent | 186 | | | — | | | 186 | | | |
| | Balance, June 30, 2022 | $ | 2,761 | | | $ | 2,079 | | | $ | 4,840 | | | |
| | Six Months Ended June 30, 2021 | | |
| (In millions) | Common
Stock | | Retained
Earnings | | Total
Shareholder's
Equity | | |
| Balance, December 31, 2020 | $ | 2,318 | | | $ | 1,879 | | | $ | 4,197 | | | |
| Net income | — | | | 209 | | | 209 | | | |
| Common stock dividends | — | | | (74) | | | (74) | | | |
| Balance, March 31, 2021 | $ | 2,318 | | | $ | 2,014 | | | $ | 4,332 | | | |
| Net income | — | | | 45 | | | 45 | | | |
| Common stock dividends | — | | | (72) | | | (72) | | | |
| | Balance, June 30, 2021 | $ | 2,318 | | | $ | 1,987 | | | $ | 4,305 | | | |
|
See the Combined Notes to Consolidated Financial Statements
2928
PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
March 31, | |
| (In millions) | (In millions) | 2022 | | 2021 | | 2022 | | 2021 | (In millions) | 2023 | | 2022 | |
| Operating revenues | Operating revenues | | | | | | | | Operating revenues | | | | |
| Electric operating revenues | Electric operating revenues | $ | 1,199 | | | $ | 1,071 | | | $ | 2,522 | | | $ | 2,195 | | Electric operating revenues | $ | 1,371 | | | $ | 1,323 | | |
| Natural gas operating revenues | Natural gas operating revenues | 37 | | | 24 | | | 120 | | | 94 | | Natural gas operating revenues | 97 | | | 83 | | |
| Revenues from alternative revenue programs | Revenues from alternative revenue programs | (17) | | | 41 | | | (22) | | | 88 | | Revenues from alternative revenue programs | 65 | | | (5) | | |
| Operating revenues from affiliates | Operating revenues from affiliates | 2 | | | 4 | | | 6 | | | 7 | | Operating revenues from affiliates | 3 | | | 3 | | |
| Total operating revenues | Total operating revenues | 1,221 | | | 1,140 | | | 2,626 | | | 2,384 | | Total operating revenues | 1,536 | | | 1,404 | | |
| Operating expenses | Operating expenses | | | | | | | | Operating expenses | | | | |
| Purchased power | Purchased power | 401 | | | 308 | | | 888 | | | 656 | | Purchased power | 572 | | | 487 | | |
| Purchased fuel | Purchased fuel | 19 | | | 9 | | | 61 | | | 41 | | Purchased fuel | 55 | | | 42 | | |
| Purchased power from affiliates | — | | | 79 | | | 50 | | | 177 | | |
| Purchased power from affiliate | | Purchased power from affiliate | — | | | 50 | | |
| Operating and maintenance | Operating and maintenance | 245 | | | 217 | | | 493 | | | 434 | | Operating and maintenance | 267 | | | 248 | | |
| Operating and maintenance from affiliates | Operating and maintenance from affiliates | 47 | | | 39 | | | 98 | | | 79 | | Operating and maintenance from affiliates | 42 | | | 51 | | |
| Depreciation and amortization | Depreciation and amortization | 240 | | | 194 | | | 459 | | | 404 | | Depreciation and amortization | 241 | | | 218 | | |
| Taxes other than income taxes | Taxes other than income taxes | 114 | | | 109 | | | 233 | | | 222 | | Taxes other than income taxes | 120 | | | 119 | | |
| Total operating expenses | Total operating expenses | 1,066 | | | 955 | | | 2,282 | | | 2,013 | | Total operating expenses | 1,297 | | | 1,215 | | |
| | Operating income | Operating income | 155 | | | 185 | | | 344 | | | 371 | | Operating income | 239 | | | 189 | | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | Other income and (deductions) | | | | |
| Interest expense, net | Interest expense, net | (73) | | | (67) | | | (143) | | | (134) | | Interest expense, net | (76) | | | (69) | | |
| | Other, net | Other, net | 19 | | | 20 | | | 37 | | | 36 | | Other, net | 26 | | | 17 | | |
| Total other income and (deductions) | Total other income and (deductions) | (54) | | | (47) | | | (106) | | | (98) | | Total other income and (deductions) | (50) | | | (52) | | |
| Income before income taxes | Income before income taxes | 101 | | | 138 | | | 238 | | | 273 | | Income before income taxes | 189 | | | 137 | | |
| Income taxes | Income taxes | 1 | | | (3) | | | 8 | | | 5 | | Income taxes | 34 | | | 7 | | |
| Equity in earnings of unconsolidated affiliate | — | | | — | | | — | | | 1 | | |
| | Net income | Net income | $ | 100 | | | $ | 141 | | | $ | 230 | | | $ | 269 | | Net income | $ | 155 | | | $ | 130 | | |
| | Comprehensive income | Comprehensive income | $ | 100 | | | $ | 141 | | | $ | 230 | | | $ | 269 | | Comprehensive income | $ | 155 | | | $ | 130 | | |
See the Combined Notes to Consolidated Financial Statements
29
PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
| | | | | | | | | | | |
| Three Months Ended
March 31, |
| (In millions) | 2023 | | 2022 |
| Cash flows from operating activities | | | |
| Net income | $ | 155 | | | $ | 130 | |
| Adjustments to reconcile net income to net cash flows from operating activities: | | | |
| Depreciation and amortization | 241 | | | 218 | |
| | | |
| | | |
| Deferred income taxes and amortization of investment tax credits | 13 | | | 2 | |
| | | |
| Other non-cash operating activities | (7) | | | 35 | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | 98 | | | (21) | |
| Receivables from and payables to affiliates, net | — | | | (51) | |
| Inventories | 4 | | | 7 | |
| Accounts payable and accrued expenses | (88) | | | (23) | |
| | | |
| Collateral (paid) received, net | (189) | | | 37 | |
| Income taxes | 20 | | | 5 | |
| Regulatory assets and liabilities, net | 27 | | | (18) | |
| Pension and non-pension postretirement benefit contributions | (7) | | | (67) | |
| Other assets and liabilities | (11) | | | (22) | |
| Net cash flows provided by operating activities | 256 | | | 232 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (561) | | | (409) | |
| | | |
| | | |
| | | |
| | | |
| Other investing activities | 8 | | | 2 | |
| Net cash flows used in investing activities | (553) | | | (407) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | (414) | | | (468) | |
| | | |
| | | |
| Issuance of long-term debt | 450 | | | 700 | |
| | | |
| Changes in Exelon intercompany money pool | 8 | | | 39 | |
| | | |
| | | |
| | | |
| Distributions to member | (112) | | | (102) | |
| Contributions from member | 405 | | | 704 | |
| | | |
| | | |
| Other financing activities | (17) | | | (9) | |
| Net cash flows provided by financing activities | 320 | | | 864 | |
| Increase in cash, restricted cash, and cash equivalents | 23 | | | 689 | |
| Cash, restricted cash, and cash equivalents at beginning of period | 373 | | | 213 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 396 | | | $ | 902 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (76) | | | $ | (55) | |
| | | |
| | | |
See the Combined Notes to Consolidated Financial Statements
30
PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWSBALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| Six Months Ended
June 30, |
| (In millions) | 2022 | | 2021 |
| Cash flows from operating activities | | | |
| Net income | $ | 230 | | | $ | 269 | |
| | | |
| Adjustments to reconcile net income to net cash flows from operating activities: | | | |
| Depreciation and amortization | 459 | | | 404 | |
| | | |
| | | |
| Deferred income taxes and amortization of investment tax credits | (7) | | | 10 | |
| | | |
| Other non-cash operating activities | 76 | | | (50) | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | (92) | | | (30) | |
| Receivables from and payables to affiliates, net | (53) | | | (22) | |
| Inventories | (7) | | | 3 | |
| Accounts payable and accrued expenses | 10 | | | (35) | |
| | | |
| Collateral received, net | 403 | | | — | |
| Income taxes | (2) | | | (1) | |
| Regulatory assets and liabilities, net | (71) | | | (33) | |
| Pension and non-pension postretirement benefit contributions | (70) | | | (40) | |
| Other assets and liabilities | (86) | | | (98) | |
| Net cash flows provided by operating activities | 790 | | | 377 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (776) | | | (889) | |
| | | |
| | | |
| | | |
| | | |
| Other investing activities | 3 | | | (2) | |
| Net cash flows used in investing activities | (773) | | | (891) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | (425) | | | (36) | |
| | | |
| | | |
| Issuance of long-term debt | 700 | | | 625 | |
| Retirement of long-term debt | (200) | | | (249) | |
| Changes in Exelon intercompany money pool | 17 | | | (12) | |
| | | |
| | | |
| | | |
| Distributions to member | (395) | | | (414) | |
| Contributions from member | 704 | | | 560 | |
| | | |
| | | |
| Other financing activities | (12) | | | (8) | |
| Net cash flows provided by financing activities | 389 | | | 466 | |
| Increase (decrease) in cash, restricted cash, and cash equivalents | 406 | | | (48) | |
| Cash, restricted cash, and cash equivalents at beginning of period | 213 | | | 160 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 619 | | | $ | 112 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (48) | | | $ | (41) | |
| | | |
| | | |
| | | | | | | | | | | |
| (In millions) | March 31, 2023 | | December 31, 2022 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 367 | | | $ | 198 | |
| Restricted cash and cash equivalents | 29 | | | 175 | |
| Accounts receivable | | | |
| Customer accounts receivable | 650 | | 734 |
| Customer allowance for credit losses | (112) | | (109) |
| Customer accounts receivable, net | 538 | | | 625 | |
| Other accounts receivable | 280 | | 300 |
| Other allowance for credit losses | (50) | | (46) |
| Other accounts receivable, net | 230 | | | 254 | |
| | | |
| Receivables from affiliates | 2 | | | 2 | |
| | | |
| | | |
| Inventories, net | | | |
| Fossil fuel | 5 | | | 18 | |
| Materials and supplies | 245 | | | 236 | |
| | | |
| | | |
| Regulatory assets | 439 | | | 455 | |
| | | |
| Other | 68 | | | 96 | |
| Total current assets | 1,923 | | | 2,059 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $2,757 and $2,618 as of March 31, 2023 and December 31, 2022, respectively) | 18,003 | | | 17,686 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 1,579 | | | 1,610 | |
| Goodwill | 4,005 | | | 4,005 | |
| Investments | 139 | | | 138 | |
| | | |
| | | |
| Prepaid pension asset | 332 | | | 353 | |
| | | |
| | | |
| Other | 227 | | | 231 | |
| Total deferred debits and other assets | 6,282 | | | 6,337 | |
| Total assets | $ | 26,208 | | | $ | 26,082 | |
See the Combined Notes to Consolidated Financial Statements
31
PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| (In millions) | June 30, 2022 | | December 31, 2021 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 278 | | | $ | 136 | |
| Restricted cash and cash equivalents | 341 | | | 77 | |
| Accounts receivable | | | |
| Customer accounts receivable | 676 | | 616 |
| Customer allowance for credit losses | (109) | | (104) |
| Customer accounts receivable, net | 567 | | | 512 | |
| Other accounts receivable | 291 | | 283 |
| Other allowance for credit losses | (42) | | (39) |
| Other accounts receivable, net | 249 | | | 244 | |
| | | |
| Receivables from affiliates | 1 | | | 2 | |
| | | |
| | | |
| Inventories, net | | | |
| Fossil fuel | 10 | | | 11 | |
| Materials and supplies | 217 | | | 209 | |
| | | |
| | | |
| Regulatory assets | 435 | | | 432 | |
| | | |
| Other | 90 | | | 69 | |
| Total current assets | 2,188 | | | 1,692 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $2,365 and $2,108 as of June 30, 2022 and December 31, 2021, respectively) | 16,915 | | | 16,498 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 1,714 | | | 1,794 | |
| Goodwill | 4,005 | | | 4,005 | |
| Investments | 139 | | | 145 | |
| | | |
| | | |
| Prepaid pension asset | 380 | | | 344 | |
| | | |
| Deferred income taxes | 6 | | | 8 | |
| Other | 245 | | | 258 | |
| Total deferred debits and other assets | 6,489 | | | 6,554 | |
| Total assets | $ | 25,592 | | | $ | 24,744 | |
See the Combined Notes to Consolidated Financial Statements
32
PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | (In millions) | (In millions) | June 30, 2022 | | December 31, 2021 | (In millions) | March 31, 2023 | | December 31, 2022 |
| LIABILITIES AND MEMBER'S EQUITY | LIABILITIES AND MEMBER'S EQUITY | | | | LIABILITIES AND MEMBER'S EQUITY | | | |
| Current liabilities | Current liabilities | | Current liabilities | |
| Short-term borrowings | Short-term borrowings | $ | 43 | | | $ | 468 | | Short-term borrowings | $ | — | | | $ | 414 | |
| Long-term debt due within one year | Long-term debt due within one year | 200 | | | 399 | | Long-term debt due within one year | 998 | | | 591 | |
| Accounts payable | Accounts payable | 574 | | | 578 | | Accounts payable | 634 | | | 771 | |
| Accrued expenses | Accrued expenses | 246 | | | 281 | | Accrued expenses | 252 | | | 260 | |
| Payables to affiliates | Payables to affiliates | 50 | | | 104 | | Payables to affiliates | 66 | | | 66 | |
| Borrowings from Exelon intercompany money pool | Borrowings from Exelon intercompany money pool | 24 | | | 7 | | Borrowings from Exelon intercompany money pool | 52 | | | 44 | |
| | Customer deposits | Customer deposits | 81 | | | 81 | | Customer deposits | 92 | | | 88 | |
| Regulatory liabilities | Regulatory liabilities | 71 | | | 68 | | Regulatory liabilities | 69 | | | 76 | |
| Unamortized energy contract liabilities | Unamortized energy contract liabilities | 11 | | | 89 | | Unamortized energy contract liabilities | 9 | | | 10 | |
| | PPA termination obligation | PPA termination obligation | 87 | | | — | | PPA termination obligation | 87 | | | 87 | |
| Other | Other | 580 | | | 171 | | Other | 149 | | | 330 | |
| Total current liabilities | Total current liabilities | 1,967 | | | 2,246 | | Total current liabilities | 2,408 | | | 2,737 | |
| Long-term debt | Long-term debt | 7,827 | | | 7,148 | | Long-term debt | 7,555 | | | 7,529 | |
| Deferred credits and other liabilities | Deferred credits and other liabilities | | Deferred credits and other liabilities | |
| Deferred income taxes and unamortized investment tax credits | Deferred income taxes and unamortized investment tax credits | 2,752 | | | 2,675 | | Deferred income taxes and unamortized investment tax credits | 2,934 | | | 2,895 | |
| Regulatory liabilities | Regulatory liabilities | 1,142 | | | 1,238 | | Regulatory liabilities | 976 | | | 1,011 | |
| Asset retirement obligations | Asset retirement obligations | 70 | | | 70 | | Asset retirement obligations | 59 | | | 59 | |
| Non-pension postretirement benefit obligations | Non-pension postretirement benefit obligations | 57 | | | 66 | | Non-pension postretirement benefit obligations | 46 | | | 50 | |
| | Unamortized energy contract liabilities | Unamortized energy contract liabilities | 38 | | | 146 | | Unamortized energy contract liabilities | 32 | | | 35 | |
| Other | Other | 615 | | | 570 | | Other | 520 | | | 536 | |
| Total deferred credits and other liabilities | Total deferred credits and other liabilities | 4,674 | | | 4,765 | | Total deferred credits and other liabilities | 4,567 | | | 4,586 | |
| Total liabilities | Total liabilities | 14,468 | | | 14,159 | | Total liabilities | 14,530 | | | 14,852 | |
| Commitments and contingencies | Commitments and contingencies | 0 | | 0 | Commitments and contingencies | | | |
| | Member's equity | Member's equity | | Member's equity | |
| Membership interest | Membership interest | 11,499 | | | 10,795 | | Membership interest | 11,987 | | | 11,582 | |
| | Undistributed losses | Undistributed losses | (375) | | | (210) | | Undistributed losses | (309) | | | (352) | |
| | Total member's equity | Total member's equity | 11,124 | | | 10,585 | | Total member's equity | 11,678 | | | 11,230 | |
| Total liabilities and member's equity | Total liabilities and member's equity | $ | 25,592 | | | $ | 24,744 | | Total liabilities and member's equity | $ | 26,208 | | | $ | 26,082 | |
See the Combined Notes to Consolidated Financial Statements
3332
PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
(Unaudited)
| | | Six Months Ended June 30, 2022 | | Three Months Ended March 31, 2023 |
| (In millions) | (In millions) | Membership Interest | | Undistributed (Losses)/Earnings | | | Total Member's Equity | (In millions) | Membership Interest | | Undistributed (Losses)/Gains | | | Total Member's Equity |
| Balance, December 31, 2021 | $ | 10,795 | | | $ | (210) | | | | $ | 10,585 | | |
| Balance, December 31, 2022 | | Balance, December 31, 2022 | $ | 11,582 | | | $ | (352) | | | | $ | 11,230 | |
| Net income | Net income | — | | | 130 | | | | 130 | | Net income | — | | | 155 | | | | 155 | |
| Distributions to member | Distributions to member | — | | | (102) | | | | (102) | | Distributions to member | — | | | (112) | | | | (112) | |
| Contributions from member | Contributions from member | 704 | | | — | | | | 704 | | Contributions from member | 405 | | | — | | | | 405 | |
| Balance, March 31, 2022 | $ | 11,499 | | | $ | (182) | | | | $ | 11,317 | | |
| Net income | — | | | 100 | | | | 100 | | |
| Distributions to member | — | | | (293) | | | | (293) | | |
| | Balance, June 30, 2022 | $ | 11,499 | | | $ | (375) | | | | $ | 11,124 | | |
| Balance, March 31, 2023 | | Balance, March 31, 2023 | $ | 11,987 | | | $ | (309) | | | | $ | 11,678 | |
| |
| | | Six Months Ended June 30, 2021 | | Three Months Ended March 31, 2022 |
| (In millions) | (In millions) | Membership Interest | | Undistributed (Losses)/Earnings | | | Total Member's Equity | (In millions) | Membership Interest | | Undistributed (Losses)/Gains | | | Total Member's Equity |
| Balance, December 31, 2020 | $ | 10,112 | | | $ | (68) | | | | $ | 10,044 | | |
| Balance, December 31, 2021 | | Balance, December 31, 2021 | $ | 10,795 | | | $ | (210) | | | | $ | 10,585 | |
| Net income | Net income | — | | | 128 | | | | 128 | | Net income | — | | | 130 | | | | 130 | |
| Distributions to member | Distributions to member | — | | | (81) | | | | (81) | | Distributions to member | — | | | (102) | | | | (102) | |
| Contributions from member | Contributions from member | 560 | | | — | | | | 560 | | Contributions from member | 704 | | | — | | | | 704 | |
| Balance, March 31, 2021 | $ | 10,672 | | | $ | (21) | | | | $ | 10,651 | | |
| Net income | — | | | 141 | | | | 141 | | |
| Distributions to member | — | | | (333) | | | | (333) | | |
| | Balance, June 30, 2021 | $ | 10,672 | | | $ | (213) | | | | $ | 10,459 | | |
| Balance, March 31, 2022 | | Balance, March 31, 2022 | $ | 11,499 | | | $ | (182) | | | | $ | 11,317 | |
| |
See the Combined Notes to Consolidated Financial Statements
3433
POTOMAC ELECTRIC POWER COMPANY
STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | | Three Months Ended
March 31, | |
| (In millions) | (In millions) | 2022 | | 2021 | | 2022 | | 2021 | | (In millions) | 2023 | | 2022 | |
| Operating revenues | Operating revenues | | | | | | | | | Operating revenues | | | | |
| Electric operating revenues | Electric operating revenues | $ | 580 | | | $ | 503 | | | $ | 1,200 | | | $ | 1,027 | | | Electric operating revenues | $ | 670 | | | $ | 620 | | |
| Revenues from alternative revenue programs | Revenues from alternative revenue programs | (1) | | | 19 | | | (7) | | | 46 | | | Revenues from alternative revenue programs | 39 | | | (7) | | |
| Operating revenues from affiliates | Operating revenues from affiliates | 2 | | | 1 | | | 2 | | | 3 | | | Operating revenues from affiliates | 1 | | | 1 | | |
| Total operating revenues | Total operating revenues | 581 | | | 523 | | | 1,195 | | | 1,076 | | | Total operating revenues | 710 | | | 614 | | |
| Operating expenses | Operating expenses | | | | | | | | | Operating expenses | | | | |
| Purchased power | Purchased power | 162 | | | 76 | | | 336 | | | 168 | | | Purchased power | 258 | | | 174 | | |
| Purchased power from affiliate | Purchased power from affiliate | — | | | 57 | | | 39 | | | 130 | | | Purchased power from affiliate | — | | | 39 | | |
| Operating and maintenance | Operating and maintenance | 72 | | | 62 | | | 145 | | | 118 | | | Operating and maintenance | 93 | | | 73 | | |
| Operating and maintenance from affiliates | Operating and maintenance from affiliates | 56 | | | 51 | | | 115 | | | 103 | | | Operating and maintenance from affiliates | 57 | | | 58 | | |
| Depreciation and amortization | Depreciation and amortization | 105 | | | 96 | | | 213 | | | 199 | | | Depreciation and amortization | 108 | | | 108 | | |
| Taxes other than income taxes | Taxes other than income taxes | 92 | | | 87 | | | 186 | | | 177 | | | Taxes other than income taxes | 94 | | | 95 | | |
| Total operating expenses | Total operating expenses | 487 | | | 429 | | | 1,034 | | | 895 | | | Total operating expenses | 610 | | | 547 | | |
| | Operating income | Operating income | 94 | | | 94 | | | 161 | | | 181 | | | Operating income | 100 | | | 67 | | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | | Other income and (deductions) | | | | |
| Interest expense, net | Interest expense, net | (38) | | | (35) | | | (74) | | | (69) | | | Interest expense, net | (39) | | | (36) | | |
| | Other, net | Other, net | 13 | | | 13 | | | 26 | | | 25 | | | Other, net | 16 | | | 13 | | |
| Total other income and (deductions) | Total other income and (deductions) | (25) | | | (22) | | | (48) | | | (44) | | | Total other income and (deductions) | (23) | | | (23) | | |
| Income before income taxes | Income before income taxes | 69 | | | 72 | | | 113 | | | 137 | | | Income before income taxes | 77 | | | 44 | | |
| Income taxes | Income taxes | (1) | | | (3) | | | (3) | | | 3 | | | Income taxes | 12 | | | (2) | | |
| | Net income | Net income | $ | 70 | | | $ | 75 | | | $ | 116 | | | $ | 134 | | | Net income | $ | 65 | | | $ | 46 | | |
| | Comprehensive income | Comprehensive income | $ | 70 | | | $ | 75 | | | $ | 116 | | | $ | 134 | | | Comprehensive income | $ | 65 | | | $ | 46 | | |
See the Combined Notes to Consolidated Financial Statements
34
POTOMAC ELECTRIC POWER COMPANY
STATEMENTS OF CASH FLOWS
(Unaudited)
| | | | | | | | | | | |
| Three Months Ended
March 31, |
| (In millions) | 2023 | | 2022 |
| Cash flows from operating activities | | | |
| Net income | $ | 65 | | | $ | 46 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 108 | | | 108 | |
| | | |
| Deferred income taxes and amortization of investment tax credits | 3 | | | (2) | |
| | | |
| Other non-cash operating activities | (10) | | | 12 | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | 52 | | | (2) | |
| Receivables from and payables to affiliates, net | 3 | | | (25) | |
| Inventories | (3) | | | — | |
| Accounts payable and accrued expenses | (27) | | | 5 | |
| Collateral (paid) received, net | (25) | | | 1 | |
| Income taxes | 8 | | | 1 | |
| Regulatory assets and liabilities, net | (3) | | | (7) | |
| Pension and non-pension postretirement benefit contributions | (4) | | | (5) | |
| Other assets and liabilities | 11 | | | (12) | |
| Net cash flows provided by operating activities | 178 | | | 120 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (264) | | | (218) | |
| | | |
| | | |
| | | |
| | | |
| Other investing activities | 8 | | | 1 | |
| Net cash flows used in investing activities | (256) | | | (217) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | (299) | | | (175) | |
| Issuance of long-term debt | 250 | | | 400 | |
| | | |
| | | |
| Dividends paid on common stock | (48) | | | (42) | |
| Contributions from parent | 243 | | | 387 | |
| | | |
| | | |
| Other financing activities | (14) | | | (5) | |
| Net cash flows provided by financing activities | 132 | | | 565 | |
| Increase in cash, restricted cash, and cash equivalents | 54 | | | 468 | |
| Cash, restricted cash, and cash equivalents at beginning of period | 99 | | | 68 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 153 | | | $ | 536 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (43) | | | $ | (36) | |
| | | |
| | | |
See the Combined Notes to Consolidated Financial Statements
35
POTOMAC ELECTRIC POWER COMPANY
STATEMENTS OF CASH FLOWSBALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| Six Months Ended
June 30, |
| (In millions) | 2022 | | 2021 |
| Cash flows from operating activities | | | |
| Net income | $ | 116 | | | $ | 134 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 213 | | | 199 | |
| | | |
| Deferred income taxes and amortization of investment tax credits | (7) | | | 10 | |
| | | |
| Other non-cash operating activities | 17 | | | (43) | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | (62) | | | (23) | |
| Receivables from and payables to affiliates, net | (39) | | | (11) | |
| Inventories | (6) | | | 1 | |
| Accounts payable and accrued expenses | 6 | | | (26) | |
| Collateral received, net | 85 | | | — | |
| Income taxes | (24) | | | (20) | |
| Regulatory assets and liabilities, net | (36) | | | (38) | |
| Pension and non-pension postretirement benefit contributions | (7) | | | (7) | |
| Other assets and liabilities | (15) | | | (41) | |
| Net cash flows provided by operating activities | 241 | | | 135 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (402) | | | (439) | |
| | | |
| | | |
| | | |
| | | |
| Other investing activities | 2 | | | (2) | |
| Net cash flows used in investing activities | (400) | | | (441) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | (132) | | | 119 | |
| Issuance of long-term debt | 400 | | | 150 | |
| Retirement of long-term debt | (200) | | | — | |
| Changes in PHI intercompany money pool | 73 | | | 9 | |
| Dividends paid on common stock | (300) | | | (123) | |
| Contributions from parent | 387 | | | 138 | |
| | | |
| | | |
| Other financing activities | (6) | | | (2) | |
| Net cash flows provided by financing activities | 222 | | | 291 | |
| Increase (decrease) in cash, restricted cash, and cash equivalents | 63 | | | (15) | |
| Cash, restricted cash, and cash equivalents at beginning of period | 68 | | | 65 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 131 | | | $ | 50 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (24) | | | $ | (15) | |
| | | |
| | | |
| | | | | | | | | | | |
| (In millions) | March 31, 2023 | | December 31, 2022 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 126 | | | $ | 45 | |
| Restricted cash and cash equivalents | 27 | | | 54 | |
| Accounts receivable | | | |
| Customer accounts receivable | 312 | | 351 |
| Customer allowance for credit losses | (49) | | (47) |
| Customer accounts receivable, net | 263 | | | 304 | |
| Other accounts receivable | 166 | | 180 |
| Other allowance for credit losses | (28) | | (25) |
| Other accounts receivable, net | 138 | | | 155 | |
| | | |
| Receivables from affiliates | 1 | | | — | |
| | | |
| | | |
| Inventories, net | 138 | | | 135 | |
| | | |
| | | |
| | | |
| Regulatory assets | 248 | | | 235 | |
| | | |
| Other | 33 | | | 53 | |
| Total current assets | 974 | | | 981 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $4,118 and $4,067 as of March 31, 2023 and December 31, 2022, respectively) | 8,955 | | | 8,794 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 424 | | | 437 | |
| Investments | 121 | | | 119 | |
| | | |
| | | |
| | | |
| Prepaid pension asset | 266 | | | 273 | |
| | | |
| Other | 55 | | | 53 | |
| Total deferred debits and other assets | 866 | | | 882 | |
| Total assets | $ | 10,795 | | | $ | 10,657 | |
See the Combined Notes to Consolidated Financial Statements
36
POTOMAC ELECTRIC POWER COMPANY
BALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| (In millions) | June 30, 2022 | | December 31, 2021 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 14 | | | $ | 34 | |
| Restricted cash and cash equivalents | 117 | | | 34 | |
| Accounts receivable | | | |
| Customer accounts receivable | 328 | | 277 |
| Customer allowance for credit losses | (42) | | (37) |
| Customer accounts receivable, net | 286 | | | 240 | |
| Other accounts receivable | 165 | | 160 |
| Other allowance for credit losses | (20) | | (16) |
| Other accounts receivable, net | 145 | | | 144 | |
| | | |
| Receivables from affiliates | 9 | | | — | |
| | | |
| | | |
| Inventories, net | 125 | | | 119 | |
| | | |
| | | |
| | | |
| Regulatory assets | 220 | | | 213 | |
| | | |
| Other | 12 | | | 25 | |
| Total current assets | 928 | | | 809 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $3,970 and $3,875 as of June 30, 2022 and December 31, 2021, respectively) | 8,365 | | | 8,104 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 478 | | | 532 | |
| Investments | 118 | | | 120 | |
| | | |
| | | |
| | | |
| Prepaid pension asset | 277 | | | 279 | |
| | | |
| Other | 60 | | | 59 | |
| Total deferred debits and other assets | 933 | | | 990 | |
| Total assets | $ | 10,226 | | | $ | 9,903 | |
See the Combined Notes to Consolidated Financial Statements
37
POTOMAC ELECTRIC POWER COMPANY
BALANCE SHEETS
(Unaudited)
| | (In millions) | (In millions) | June 30, 2022 | | December 31, 2021 | (In millions) | March 31, 2023 | | December 31, 2022 |
| LIABILITIES AND SHAREHOLDER'S EQUITY | LIABILITIES AND SHAREHOLDER'S EQUITY | | | | LIABILITIES AND SHAREHOLDER'S EQUITY | | | |
| Current liabilities | Current liabilities | | Current liabilities | |
| Short-term borrowings | Short-term borrowings | $ | 43 | | | $ | 175 | | Short-term borrowings | $ | — | | | $ | 299 | |
| Long-term debt due within one year | Long-term debt due within one year | 114 | | | 313 | | Long-term debt due within one year | 405 | | | 4 | |
| Accounts payable | Accounts payable | 269 | | | 272 | | Accounts payable | 311 | | | 382 | |
| Accrued expenses | Accrued expenses | 124 | | | 160 | | Accrued expenses | 131 | | | 125 | |
| Payables to affiliates | Payables to affiliates | 29 | | | 59 | | Payables to affiliates | 38 | | | 34 | |
| | Borrowings from PHI intercompany money pool | 73 | | | — | | |
| | Customer deposits | Customer deposits | 36 | | | 35 | | Customer deposits | 41 | | | 39 | |
| Regulatory liabilities | Regulatory liabilities | 12 | | | 14 | | Regulatory liabilities | 5 | | | 6 | |
| Merger related obligation | Merger related obligation | 25 | | | 27 | | Merger related obligation | 25 | | | 26 | |
| | Other | Other | 149 | | | 55 | | Other | 75 | | | 93 | |
| Total current liabilities | Total current liabilities | 874 | | | 1,110 | | Total current liabilities | 1,031 | | | 1,008 | |
| Long-term debt | Long-term debt | 3,528 | | | 3,132 | | Long-term debt | 3,590 | | | 3,747 | |
| | Deferred credits and other liabilities | Deferred credits and other liabilities | | Deferred credits and other liabilities | |
| Deferred income taxes and unamortized investment tax credits | Deferred income taxes and unamortized investment tax credits | 1,314 | | | 1,275 | | Deferred income taxes and unamortized investment tax credits | 1,398 | | | 1,382 | |
| Regulatory liabilities | Regulatory liabilities | 507 | | | 549 | | Regulatory liabilities | 435 | | | 455 | |
| Asset retirement obligations | Asset retirement obligations | 45 | | | 45 | | Asset retirement obligations | 39 | | | 39 | |
| | Non-pension postretirement benefit obligations | — | | | 3 | | |
| | | Other | Other | 280 | | | 314 | | Other | 260 | | | 244 | |
| Total deferred credits and other liabilities | Total deferred credits and other liabilities | 2,146 | | | 2,186 | | Total deferred credits and other liabilities | 2,132 | | | 2,120 | |
| Total liabilities | Total liabilities | 6,548 | | | 6,428 | | Total liabilities | 6,753 | | | 6,875 | |
| Commitments and contingencies | Commitments and contingencies | 0 | | 0 | Commitments and contingencies | | | |
| Shareholder's equity | Shareholder's equity | | Shareholder's equity | |
| Common stock | Common stock | 2,689 | | | 2,302 | | Common stock | 3,010 | | | 2,767 | |
| | Retained earnings | Retained earnings | 989 | | | 1,173 | | Retained earnings | 1,032 | | | 1,015 | |
| | Total shareholder's equity | Total shareholder's equity | 3,678 | | | 3,475 | | Total shareholder's equity | 4,042 | | | 3,782 | |
| Total liabilities and shareholder's equity | Total liabilities and shareholder's equity | $ | 10,226 | | | $ | 9,903 | | Total liabilities and shareholder's equity | $ | 10,795 | | | $ | 10,657 | |
See the Combined Notes to Consolidated Financial Statements
3837
POTOMAC ELECTRIC POWER COMPANY
STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY
(Unaudited)
| | | Six Months Ended June 30, 2022 | | Three Months Ended March 31, 2023 |
| (In millions) | (In millions) | Common Stock | | | Retained Earnings | | Total Shareholder's Equity | (In millions) | Common Stock | | | Retained Earnings | | Total Shareholder's Equity |
| Balance, December 31, 2021 | $ | 2,302 | | | | $ | 1,173 | | | $ | 3,475 | | |
| Balance, December 31, 2022 | | Balance, December 31, 2022 | $ | 2,767 | | | | $ | 1,015 | | | $ | 3,782 | |
| Net income | Net income | — | | | | 46 | | | 46 | | Net income | — | | | | 65 | | | 65 | |
| Common stock dividends | Common stock dividends | — | | | | (42) | | | (42) | | Common stock dividends | — | | | | (48) | | | (48) | |
| Contributions from parent | Contributions from parent | 387 | | | | — | | | 387 | | Contributions from parent | 243 | | | | — | | | 243 | |
| Balance, March 31, 2022 | $ | 2,689 | | | | $ | 1,177 | | | $ | 3,866 | | |
| Net income | — | | | | 70 | | | 70 | | |
| | Common stock dividends | — | | | | (258) | | | (258) | | |
| | Balance, June 30, 2022 | $ | 2,689 | | | | $ | 989 | | | $ | 3,678 | | |
| Balance, March 31, 2023 | | Balance, March 31, 2023 | $ | 3,010 | | | | $ | 1,032 | | | $ | 4,042 | |
| |
| | | Six Months Ended June 30, 2021 | | Three Months Ended March 31, 2022 |
| (In millions) | (In millions) | Common Stock | | | Retained Earnings | | Total Shareholder's Equity | (In millions) | Common Stock | | | Retained Earnings | | Total Shareholder's Equity |
| Balance, December 31, 2020 | $ | 2,058 | | | | $ | 1,145 | | | $ | 3,203 | | |
| Balance, December 31, 2021 | | Balance, December 31, 2021 | $ | 2,302 | | | | $ | 1,173 | | | $ | 3,475 | |
| Net income | Net income | — | | | | 59 | | | 59 | | Net income | — | | | | 46 | | | 46 | |
| Common stock dividends | Common stock dividends | — | | | | (28) | | | (28) | | Common stock dividends | — | | | | (42) | | | (42) | |
| Contributions from parent | Contributions from parent | 138 | | | | — | | | 138 | | Contributions from parent | 387 | | | | — | | | 387 | |
| Balance, March 31, 2021 | $ | 2,196 | | | | $ | 1,176 | | | $ | 3,372�� | | |
| Net income | — | | | | 75 | | | 75 | | |
| | Common stock dividends | — | | | | (95) | | | (95) | | |
| | Balance, June 30, 2021 | $ | 2,196 | | | | $ | 1,156 | | | $ | 3,352 | | |
| Balance, March 31, 2022 | | Balance, March 31, 2022 | $ | 2,689 | | | | $ | 1,177 | | | $ | 3,866 | |
| |
See the Combined Notes to Consolidated Financial Statements
3938
DELMARVA POWER & LIGHT COMPANY
STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
March 31, | |
| (In millions) | (In millions) | 2022 | | 2021 | | 2022 | | 2021 | (In millions) | 2023 | | 2022 | |
| Operating revenues | Operating revenues | | | | | | | | Operating revenues | | | | |
| Electric operating revenues | Electric operating revenues | $ | 295 | | | $ | 262 | | | $ | 643 | | | $ | 562 | | Electric operating revenues | $ | 366 | | | $ | 348 | | |
| Natural gas operating revenues | Natural gas operating revenues | 37 | | | 24 | | | 120 | | | 95 | | Natural gas operating revenues | 97 | | | 83 | | |
| Revenues from alternative revenue programs | Revenues from alternative revenue programs | (2) | | | 10 | | | (3) | | | 19 | | Revenues from alternative revenue programs | 9 | | | (1) | | |
| Operating revenues from affiliates | Operating revenues from affiliates | 2 | | | 2 | | | 3 | | | 4 | | Operating revenues from affiliates | 2 | | | 1 | | |
| Total operating revenues | Total operating revenues | 332 | | | 298 | | | 763 | | | 680 | | Total operating revenues | 474 | | | 431 | | |
| Operating expenses | Operating expenses | | | | | | | | Operating expenses | | | | |
| Purchased power | Purchased power | 116 | | | 82 | | | 253 | | | 185 | | Purchased power | 166 | | | 137 | | |
| Purchased fuel | Purchased fuel | 19 | | | 9 | | | 61 | | | 41 | | Purchased fuel | 55 | | | 42 | | |
| Purchased power from affiliates | — | | | 17 | | | 10 | | | 37 | | |
| Purchased power from affiliate | | Purchased power from affiliate | — | | | 10 | | |
| Operating and maintenance | Operating and maintenance | 45 | | | 41 | | | 97 | | | 85 | | Operating and maintenance | 46 | | | 51 | | |
| Operating and maintenance from affiliates | Operating and maintenance from affiliates | 43 | | | 39 | | | 84 | | | 79 | | Operating and maintenance from affiliates | 41 | | | 42 | | |
| Depreciation and amortization | Depreciation and amortization | 56 | | | 51 | | | 113 | | | 104 | | Depreciation and amortization | 60 | | | 57 | | |
| Taxes other than income taxes | Taxes other than income taxes | 17 | | | 16 | | | 35 | | | 33 | | Taxes other than income taxes | 20 | | | 18 | | |
| Total operating expenses | Total operating expenses | 296 | | | 255 | | | 653 | | | 564 | | Total operating expenses | 388 | | | 357 | | |
| | Operating income | Operating income | 36 | | | 43 | | | 110 | | | 116 | | Operating income | 86 | | | 74 | | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | Other income and (deductions) | | | | |
| Interest expense, net | Interest expense, net | (17) | | | (16) | | | (33) | | | (30) | | Interest expense, net | (17) | | | (16) | | |
| Other, net | Other, net | 4 | | | 4 | | | 6 | | | 6 | | Other, net | 3 | | | 2 | | |
| Total other income and (deductions) | Total other income and (deductions) | (13) | | | (12) | | | (27) | | | (24) | | Total other income and (deductions) | (14) | | | (14) | | |
| Income before income taxes | Income before income taxes | 23 | | | 31 | | | 83 | | | 92 | | Income before income taxes | 72 | | | 60 | | |
| Income taxes | Income taxes | 2 | | | 1 | | | 6 | | | 6 | | Income taxes | 12 | | | 4 | | |
| | Net income | Net income | $ | 21 | | | $ | 30 | | | $ | 77 | | | $ | 86 | | Net income | $ | 60 | | | $ | 56 | | |
| Comprehensive income | Comprehensive income | $ | 21 | | | $ | 30 | | | $ | 77 | | | $ | 86 | | Comprehensive income | $ | 60 | | | $ | 56 | | |
See the Combined Notes to Consolidated Financial Statements
39
DELMARVA POWER & LIGHT COMPANY
STATEMENTS OF CASH FLOWS
(Unaudited)
| | | | | | | | | | | |
| Three Months Ended
March 31, |
| (In millions) | 2023 | | 2022 |
| Cash flows from operating activities | | | |
| Net income | $ | 60 | | | $ | 56 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 60 | | | 57 | |
| | | |
| Deferred income taxes and amortization of investment tax credits | 3 | | | 5 | |
| | | |
| Other non-cash operating activities | (1) | | | 9 | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | 23 | | | (17) | |
| Receivables from and payables to affiliates, net | 4 | | | (17) | |
| Inventories | 10 | | | 8 | |
| Accounts payable and accrued expenses | (16) | | | 15 | |
| Collateral (paid) received, net | (120) | | | 30 | |
| Income taxes | 9 | | | (1) | |
| Regulatory assets and liabilities, net | 27 | | | — | |
| Pension and non-pension postretirement benefit contributions | — | | | (1) | |
| Other assets and liabilities | 1 | | | 3 | |
| Net cash flows provided by operating activities | 60 | | | 147 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (134) | | | (103) | |
| | | |
| | | |
| | | |
| Other investing activities | — | | | 1 | |
| Net cash flows used in investing activities | (134) | | | (102) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | (115) | | | (149) | |
| Issuance of long-term debt | 125 | | | 125 | |
| | | |
| | | |
| Dividends paid on common stock | (42) | | | (41) | |
| Contributions from parent | 99 | | | 144 | |
| Other financing activities | (2) | | | (2) | |
| Net cash flows provided by financing activities | 65 | | | 77 | |
| (Decrease) increase in cash, restricted cash, and cash equivalents | (9) | | | 122 | |
| Cash, restricted cash, and cash equivalents at beginning of period | 152 | | | 71 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 143 | | | $ | 193 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (3) | | | $ | (8) | |
| | | |
| | | |
See the Combined Notes to Consolidated Financial Statements
40
DELMARVA POWER & LIGHT COMPANY
STATEMENTS OF CASH FLOWSBALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| Six Months Ended
June 30, |
| (In millions) | 2022 | | 2021 |
| Cash flows from operating activities | | | |
| Net income | $ | 77 | | | $ | 86 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 113 | | | 104 | |
| | | |
| Deferred income taxes and amortization of investment tax credits | 3 | | | 4 | |
| | | |
| Other non-cash operating activities | 13 | | | (12) | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | (8) | | | 24 | |
| Receivables from and payables to affiliates, net | (3) | | | (12) | |
| Inventories | 1 | | | — | |
| Accounts payable and accrued expenses | 12 | | | 7 | |
| Collateral received, net | 180 | | | — | |
| Income taxes | 6 | | | 14 | |
| Regulatory assets and liabilities, net | (11) | | | (13) | |
| Pension and non-pension postretirement benefit contributions | (1) | | | — | |
| Other assets and liabilities | 1 | | | (9) | |
| Net cash flows provided by operating activities | 383 | | | 193 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (194) | | | (211) | |
| | | |
| | | |
| Changes in PHI intercompany money pool | (73) | | | (9) | |
| Other investing activities | 2 | | | 1 | |
| Net cash flows used in investing activities | (265) | | | (219) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | (149) | | | (146) | |
| Issuance of long-term debt | 125 | | | 125 | |
| | | |
| | | |
| Dividends paid on common stock | (56) | | | (63) | |
| Contributions from parent | 144 | | | 120 | |
| Other financing activities | (4) | | | (3) | |
| Net cash flows provided by financing activities | 60 | | | 33 | |
| Increase in cash, restricted cash, and cash equivalents | 178 | | | 7 | |
| Cash, restricted cash, and cash equivalents at beginning of period | 71 | | | 15 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 249 | | | $ | 22 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (5) | | | $ | (14) | |
| | | |
| | | |
| | | | | | | | | | | |
| (In millions) | March 31, 2023 | | December 31, 2022 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 142 | | | $ | 31 | |
| Restricted cash and cash equivalents | 1 | | | 121 | |
| Accounts receivable | | | |
| Customer accounts receivable | 182 | | 204 |
| Customer allowance for credit losses | (26) | | (21) |
| Customer accounts receivable, net | 156 | | | 183 | |
| Other accounts receivable | 48 | | 52 |
| Other allowance for credit losses | (8) | | (7) |
| Other accounts receivable, net | 40 | | | 45 | |
| | | |
| | | |
| Inventories, net | | | |
| Fossil fuel | 5 | | | 18 | |
| Materials and supplies | 61 | | | 58 | |
| | | |
| | | |
| Regulatory assets | 63 | | | 80 | |
| | | |
| Other | 30 | | | 37 | |
| Total current assets | 498 | | | 573 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $1,811 and $1,772 as of March 31, 2023 and December 31, 2022, respectively) | 4,902 | | | 4,820 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 202 | | | 202 | |
| | | |
| | | |
| Prepaid pension asset | 148 | | | 153 | |
| Other | 54 | | | 54 | |
| Total deferred debits and other assets | 404 | | | 409 | |
| Total assets | $ | 5,804 | | | $ | 5,802 | |
See the Combined Notes to Consolidated Financial Statements
41
DELMARVA POWER & LIGHT COMPANY
BALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| (In millions) | June 30, 2022 | | December 31, 2021 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 26 | | | $ | 28 | |
| Restricted cash and cash equivalents | 223 | | | 43 | |
| Accounts receivable | | | |
| Customer accounts receivable | 154 | | 149 |
| Customer allowance for credit losses | (22) | | (18) |
| Customer accounts receivable, net | 132 | | | 131 | |
| Other accounts receivable | 55 | | 58 |
| Other allowance for credit losses | (8) | | (8) |
| Other accounts receivable, net | 47 | | | 50 | |
| Receivables from affiliates | — | | | 1 | |
| Receivable from PHI intercompany pool | 73 | | | — | |
| Inventories, net | | | |
| Fossil fuel | 10 | | | 11 | |
| Materials and supplies | 54 | | | 54 | |
| Prepaid utility taxes | — | | | 20 | |
| | | |
| Regulatory assets | 68 | | | 68 | |
| | | |
| Other | 29 | | | 16 | |
| Total current assets | 662 | | | 422 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $1,704 and $1,635 as of June 30, 2022 and December 31, 2021, respectively) | 4,661 | | | 4,560 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 204 | | | 212 | |
| | | |
| | | |
| Prepaid pension asset | 156 | | | 157 | |
| Other | 59 | | | 61 | |
| Total deferred debits and other assets | 419 | | | 430 | |
| Total assets | $ | 5,742 | | | $ | 5,412 | |
See the Combined Notes to Consolidated Financial Statements
42
DELMARVA POWER & LIGHT COMPANY
BALANCE SHEETS
(Unaudited)
| | (In millions) | (In millions) | June 30, 2022 | | December 31, 2021 | (In millions) | March 31, 2023 | | December 31, 2022 |
| LIABILITIES AND SHAREHOLDER'S EQUITY | LIABILITIES AND SHAREHOLDER'S EQUITY | | | | LIABILITIES AND SHAREHOLDER'S EQUITY | | | |
| Current liabilities | Current liabilities | | Current liabilities | |
| Short-term borrowings | Short-term borrowings | $ | — | | | $ | 149 | | Short-term borrowings | $ | — | | | $ | 115 | |
| Long-term debt due within one year | Long-term debt due within one year | 84 | | | 83 | | Long-term debt due within one year | 584 | | | 584 | |
| Accounts payable | Accounts payable | 141 | | | 131 | | Accounts payable | 148 | | | 172 | |
| Accrued expenses | Accrued expenses | 40 | | | 40 | | Accrued expenses | 51 | | | 41 | |
| Payables to affiliates | Payables to affiliates | 29 | | | 33 | | Payables to affiliates | 26 | | | 22 | |
| | Customer deposits | Customer deposits | 27 | | | 28 | | Customer deposits | 30 | | | 29 | |
| Regulatory liabilities | Regulatory liabilities | 31 | | | 25 | | Regulatory liabilities | 49 | | | 44 | |
| Other | Other | 239 | | | 59 | | Other | 17 | | | 136 | |
| Total current liabilities | Total current liabilities | 591 | | | 548 | | Total current liabilities | 905 | | | 1,143 | |
| Long-term debt | Long-term debt | 1,854 | | | 1,727 | | Long-term debt | 1,477 | | | 1,354 | |
| Deferred credits and other liabilities | Deferred credits and other liabilities | | Deferred credits and other liabilities | |
| Deferred income taxes and unamortized investment tax credits | Deferred income taxes and unamortized investment tax credits | 830 | | | 803 | | Deferred income taxes and unamortized investment tax credits | 882 | | | 869 | |
| Regulatory liabilities | Regulatory liabilities | 415 | | | 441 | | Regulatory liabilities | 374 | | | 380 | |
| Asset retirement obligations | Asset retirement obligations | 16 | | | 16 | | Asset retirement obligations | 13 | | | 13 | |
| | Non-pension postretirement benefits obligations | Non-pension postretirement benefits obligations | 10 | | | 11 | | Non-pension postretirement benefits obligations | 9 | | | 9 | |
| Other | Other | 84 | | | 89 | | Other | 77 | | | 84 | |
| Total deferred credits and other liabilities | Total deferred credits and other liabilities | 1,355 | | | 1,360 | | Total deferred credits and other liabilities | 1,355 | | | 1,355 | |
| Total liabilities | Total liabilities | 3,800 | | | 3,635 | | Total liabilities | 3,737 | | | 3,852 | |
| Commitments and contingencies | Commitments and contingencies | 0 | | 0 | Commitments and contingencies | | | |
| Shareholder's equity | Shareholder's equity | | Shareholder's equity | |
| Common stock | Common stock | 1,353 | | | 1,209 | | Common stock | 1,455 | | | 1,356 | |
| | Retained earnings | Retained earnings | 589 | | | 568 | | Retained earnings | 612 | | | 594 | |
| Total shareholder's equity | Total shareholder's equity | 1,942 | | | 1,777 | | Total shareholder's equity | 2,067 | | | 1,950 | |
| Total liabilities and shareholder's equity | Total liabilities and shareholder's equity | $ | 5,742 | | | $ | 5,412 | | Total liabilities and shareholder's equity | $ | 5,804 | | | $ | 5,802 | |
See the Combined Notes to Consolidated Financial Statements
4342
DELMARVA POWER & LIGHT COMPANY
STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY
(Unaudited)
| | | Six Months Ended June 30, 2022 | | Three Months Ended March 31, 2023 |
| (In millions) | (In millions) | Common Stock | | | Retained Earnings | | Total Shareholder's Equity | (In millions) | Common Stock | | | Retained Earnings | | Total Shareholder's Equity |
| Balance, December 31, 2021 | $ | 1,209 | | | | $ | 568 | | | $ | 1,777 | | |
| Balance, December 31, 2022 | | Balance, December 31, 2022 | $ | 1,356 | | | | $ | 594 | | | $ | 1,950 | |
| Net income | Net income | — | | | | 56 | | | 56 | | Net income | — | | | | 60 | | | 60 | |
| Common stock dividends | Common stock dividends | — | | | | (41) | | | (41) | | Common stock dividends | — | | | | (42) | | | (42) | |
| Contributions from parent | Contributions from parent | 144 | | | | — | | | 144 | | Contributions from parent | 99 | | | | — | | | 99 | |
| Balance, March 31, 2022 | $ | 1,353 | | | | $ | 583 | | | $ | 1,936 | | |
| Net income | — | | | | 21 | | | 21 | | |
| Common stock dividends | — | | | | (15) | | | (15) | | |
| Balance, March 31, 2023 | | Balance, March 31, 2023 | $ | 1,455 | | | | $ | 612 | | | $ | 2,067 | |
| | Balance, June 30, 2022 | $ | 1,353 | | | | $ | 589 | | | $ | 1,942 | | |
|
| | | Six Months Ended June 30, 2021 | | Three Months Ended March 31, 2022 |
| (In millions) | (In millions) | Common Stock | | | Retained Earnings | | Total Shareholder's Equity | (In millions) | Common Stock | | | Retained Earnings | | Total Shareholder's Equity |
| Balance, December 31, 2020 | $ | 1,089 | | | | $ | 587 | | | $ | 1,676 | | |
| Balance, December 31, 2021 | | Balance, December 31, 2021 | $ | 1,209 | | | | $ | 568 | | | $ | 1,777 | |
| Net income | Net income | — | | | | 56 | | | 56 | | Net income | — | | | | 56 | | | 56 | |
| Common stock dividends | Common stock dividends | — | | | | (40) | | | (40) | | Common stock dividends | — | | | | (41) | | | (41) | |
| Contributions from parent | Contributions from parent | 120 | | | | — | | | 120 | | Contributions from parent | 144 | | | | — | | | 144 | |
| Balance, March 31, 2021 | $ | 1,209 | | | | $ | 603 | | | $ | 1,812 | | |
| Net income | — | | | | 30 | | | 30 | | |
| Common stock dividends | — | | | | (23) | | | (23) | | |
| Balance, March 31, 2022 | | Balance, March 31, 2022 | $ | 1,353 | | | | $ | 583 | | | $ | 1,936 | |
| | Balance, June 30, 2021 | $ | 1,209 | | | | $ | 610 | | | $ | 1,819 | | |
|
See the Combined Notes to Consolidated Financial Statements
4443
ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, | | Three Months Ended
March 31, | |
| (In millions) | (In millions) | 2022 | | 2021 | | 2022 | | 2021 | (In millions) | 2023 | | 2022 | |
| Operating revenues | Operating revenues | | | | | | | | Operating revenues | | | | |
| Electric operating revenues | Electric operating revenues | $ | 323 | | | $ | 306 | | | $ | 668 | | | $ | 605 | | Electric operating revenues | $ | 335 | | | $ | 345 | | |
| Revenues from alternative revenue programs | Revenues from alternative revenue programs | (15) | | | 12 | | | (12) | | | 23 | | Revenues from alternative revenue programs | 17 | | | 3 | | |
| Operating revenues from affiliates | Operating revenues from affiliates | 1 | | | 1 | | | 2 | | | 1 | | Operating revenues from affiliates | 1 | | | 1 | | |
| Total operating revenues | Total operating revenues | 309 | | | 319 | | | 658 | | | 629 | | Total operating revenues | 353 | | | 349 | | |
| Operating expenses | Operating expenses | | | | | | | | Operating expenses | | | | |
| Purchased power | Purchased power | 123 | | | 149 | | | 299 | | | 302 | | Purchased power | 148 | | | 176 | | |
| Purchased power from affiliate | Purchased power from affiliate | — | | | 5 | | | 2 | | | 9 | | Purchased power from affiliate | — | | | 2 | | |
| Operating and maintenance | Operating and maintenance | 50 | | | 39 | | | 97 | | | 82 | | Operating and maintenance | 44 | | | 47 | | |
| Operating and maintenance from affiliates | Operating and maintenance from affiliates | 36 | | | 34 | | | 73 | | | 68 | | Operating and maintenance from affiliates | 37 | | | 37 | | |
| Depreciation and amortization | Depreciation and amortization | 72 | | | 40 | | | 118 | | | 87 | | Depreciation and amortization | 67 | | | 47 | | |
| Taxes other than income taxes | Taxes other than income taxes | 2 | | | 2 | | | 4 | | | 4 | | Taxes other than income taxes | 2 | | | 2 | | |
| Total operating expenses | Total operating expenses | 283 | | | 269 | | | 593 | | | 552 | | Total operating expenses | 298 | | | 311 | | |
| | Operating income | Operating income | 26 | | | 50 | | | 65 | | | 77 | | Operating income | 55 | | | 38 | | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | Other income and (deductions) | | | | |
| Interest expense, net | Interest expense, net | (17) | | | (14) | | | (32) | | | (29) | | Interest expense, net | (16) | | | (14) | | |
| | Other, net | Other, net | 2 | | | — | | | 5 | | | 2 | | Other, net | 5 | | | 3 | | |
| Total other income and (deductions) | Total other income and (deductions) | (15) | | | (14) | | | (27) | | | (27) | | Total other income and (deductions) | (11) | | | (11) | | |
| Income before income taxes | Income before income taxes | 11 | | | 36 | | | 38 | | | 50 | | Income before income taxes | 44 | | | 27 | | |
| Income taxes | Income taxes | — | | | (1) | | | 1 | | | (1) | | Income taxes | 11 | | | 1 | | |
| | Net income | Net income | $ | 11 | | | $ | 37 | | | $ | 37 | | | $ | 51 | | Net income | $ | 33 | | | $ | 26 | | |
| Comprehensive income | Comprehensive income | $ | 11 | | | $ | 37 | | | $ | 37 | | | $ | 51 | | Comprehensive income | $ | 33 | | | $ | 26 | | |
See the Combined Notes to Consolidated Financial Statements
44
ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
| | | | | | | | | | | |
| Three Months Ended
March 31, |
| (In millions) | 2023 | | 2022 |
| Cash flows from operating activities | | | |
| Net income | $ | 33 | | | $ | 26 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 67 | | | 47 | |
| Deferred income taxes and amortization of investment tax credits | 6 | | | 1 | |
| Other non-cash operating activities | (9) | | | 2 | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | 24 | | | (1) | |
| Receivables from and payables to affiliates, net | (1) | | | (6) | |
| Inventories | (3) | | | (1) | |
| Accounts payable and accrued expenses | (15) | | | (17) | |
| Collateral paid, net | (44) | | | (3) | |
| Income taxes | 5 | | | — | |
| Regulatory assets and liabilities, net | 3 | | | (3) | |
| Pension and non-pension postretirement benefit contributions | (1) | | | (7) | |
| Other assets and liabilities | (21) | | | 6 | |
| Net cash flows provided by operating activities | 44 | | | 44 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (161) | | | (87) | |
| | | |
| | | |
| | | |
| Net cash flows used in investing activities | (161) | | | (87) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | — | | | (144) | |
| | | |
| | | |
| Issuance of long-term debt | 75 | | | 175 | |
| | | |
| | | |
| Dividends paid on common stock | (21) | | | (19) | |
| Contributions from parent | 63 | | | 173 | |
| Other financing activities | (1) | | | (3) | |
| Net cash flows provided by financing activities | 116 | | | 182 | |
| (Decrease) increase in cash and cash equivalents | (1) | | | 139 | |
| Cash and cash equivalents at beginning of period | 72 | | | 29 | |
| Cash and cash equivalents at end of period | $ | 71 | | | $ | 168 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (30) | | | $ | (10) | |
| | | |
| | | |
See the Combined Notes to Consolidated Financial Statements
45
ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWSBALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| Six Months Ended
June 30, |
| (In millions) | 2022 | | 2021 |
| Cash flows from operating activities | | | |
| Net income | $ | 37 | | | $ | 51 | |
| Adjustments to reconcile net income to net cash flows provided by operating activities: | | | |
| Depreciation and amortization | 118 | | | 87 | |
| Deferred income taxes and amortization of investment tax credits | — | | | (2) | |
| Other non-cash operating activities | 25 | | | (14) | |
| Changes in assets and liabilities: | | | |
| Accounts receivable | (20) | | | (30) | |
| Receivables from and payables to affiliates, net | (10) | | | 4 | |
| Inventories | (2) | | | 2 | |
| Accounts payable and accrued expenses | 9 | | | (2) | |
| Collateral received, net | 137 | | | — | |
| Income taxes | 8 | | | 2 | |
| Regulatory assets and liabilities, net | (11) | | | 18 | |
| Pension and non-pension postretirement benefit contributions | (7) | | | (3) | |
| Other assets and liabilities | (63) | | | (43) | |
| Net cash flows provided by operating activities | 221 | | | 70 | |
| Cash flows from investing activities | | | |
| Capital expenditures | (179) | | | (239) | |
| | | |
| | | |
| | | |
| Net cash flows used in investing activities | (179) | | | (239) | |
| Cash flows from financing activities | | | |
| Changes in short-term borrowings | (144) | | | (9) | |
| | | |
| | | |
| Issuance of long-term debt | 175 | | | 350 | |
| Retirement of long-term debt | — | | | (249) | |
| | | |
| Dividends paid on common stock | (38) | | | (229) | |
| Contributions from parent | 173 | | | 303 | |
| Other financing activities | (4) | | | (4) | |
| Net cash flows provided by financing activities | 162 | | | 162 | |
| Increase (decrease) in cash, restricted cash, and cash equivalents | 204 | | | (7) | |
| Cash, restricted cash, and cash equivalents at beginning of period | 29 | | | 30 | |
| Cash, restricted cash, and cash equivalents at end of period | $ | 233 | | | $ | 23 | |
| | | |
| Supplemental cash flow information | | | |
| Decrease in capital expenditures not paid | $ | (19) | | | $ | (13) | |
| | | |
| | | |
| | | | | | | | | | | |
| (In millions) | March 31, 2023 | | December 31, 2022 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 71 | | | $ | 72 | |
| | | |
| Accounts receivable | | | |
| Customer accounts receivable | 156 | | 179 |
| Customer allowance for credit losses | (37) | | (41) |
| Customer accounts receivable, net | 119 | | | 138 | |
| Other accounts receivable | 64 | | 70 |
| Other allowance for credit losses | (14) | | (14) |
| Other accounts receivable, net | 50 | | | 56 | |
| | | |
| Receivables from affiliates | 2 | | | 1 | |
| | | |
| Inventories, net | 46 | | | 43 | |
| | | |
| | | |
| | | |
| Regulatory assets | 114 | | | 130 | |
| Other | 5 | | | 3 | |
| Total current assets | 407 | | | 443 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $1,583 and $1,551 as of March 31, 2023 and December 31, 2022, respectively) | 4,067 | | | 3,990 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 492 | | | 494 | |
| | | |
| | | |
| | | |
| Prepaid pension asset | 14 | | | 18 | |
| | | |
| Other | 33 | | | 34 | |
| Total deferred debits and other assets | 539 | | | 546 | |
| Total assets | $ | 5,013 | | | $ | 4,979 | |
See the Combined Notes to Consolidated Financial Statements
46
ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | | | | | | | | | | |
| (In millions) | June 30, 2022 | | December 31, 2021 |
| ASSETS | | | |
| Current assets | | | |
| Cash and cash equivalents | $ | 233 | | | $ | 29 | |
| | | |
| Accounts receivable | | | |
| Customer accounts receivable | 194 | | 190 |
| Customer allowance for credit losses | (45) | | (49) |
| Customer accounts receivable, net | 149 | | | 141 | |
| Other accounts receivable | 70 | | 76 |
| Other allowance for credit losses | (14) | | (15) |
| Other accounts receivable, net | 56 | | | 61 | |
| | | |
| Receivables from affiliates | 1 | | | 2 | |
| | | |
| Inventories, net | 38 | | | 36 | |
| | | |
| | | |
| Prepaid utility taxes | 40 | | | — | |
| Regulatory assets | 135 | | | 61 | |
| Other | 7 | | | 3 | |
| Total current assets | 659 | | | 333 | |
| Property, plant, and equipment (net of accumulated depreciation and amortization of $1,491 and $1,420 as of June 30, 2022 and December 31, 2021, respectively) | 3,798 | | | 3,729 | |
| Deferred debits and other assets | | | |
| Regulatory assets | 535 | | | 430 | |
| | | |
| | | |
| | | |
| Prepaid pension asset | 26 | | | 27 | |
| | | |
| Other | 34 | | | 37 | |
| Total deferred debits and other assets | 595 | | | 494 | |
| Total assets | $ | 5,052 | | | $ | 4,556 | |
See the Combined Notes to Consolidated Financial Statements
47
ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED BALANCE SHEETS
(Unaudited)
| | (In millions) | (In millions) | June 30, 2022 | | December 31, 2021 | (In millions) | March 31, 2023 | | December 31, 2022 |
| LIABILITIES AND SHAREHOLDER'S EQUITY | LIABILITIES AND SHAREHOLDER'S EQUITY | | | | LIABILITIES AND SHAREHOLDER'S EQUITY | | | |
| Current liabilities | Current liabilities | | Current liabilities | |
| Short-term borrowings | $ | — | | | $ | 144 | | |
| | Long-term debt due within one year | Long-term debt due within one year | 3 | | | 3 | | Long-term debt due within one year | $ | 3 | | | $ | 3 | |
| Accounts payable | Accounts payable | 157 | | | 165 | | Accounts payable | 167 | | | 206 | |
| Accrued expenses | Accrued expenses | 43 | | | 44 | | Accrued expenses | 46 | | | 47 | |
| Payables to affiliates | Payables to affiliates | 20 | | | 31 | | Payables to affiliates | 26 | | | 26 | |
| | Customer deposits | Customer deposits | 18 | | | 18 | | Customer deposits | 21 | | | 21 | |
| Regulatory liabilities | Regulatory liabilities | 29 | | | 28 | | Regulatory liabilities | 15 | | | 26 | |
| PPA termination obligation | PPA termination obligation | 87 | | | — | | PPA termination obligation | 87 | | | 87 | |
| Other | Other | 149 | | | 12 | | Other | 12 | | | 58 | |
| Total current liabilities | Total current liabilities | 506 | | | 445 | | Total current liabilities | 377 | | | 474 | |
| Long-term debt | Long-term debt | 1,754 | | | 1,579 | | Long-term debt | 1,828 | | | 1,754 | |
| Deferred credits and other liabilities | Deferred credits and other liabilities | | Deferred credits and other liabilities | |
| Deferred income taxes and unamortized investment tax credits | Deferred income taxes and unamortized investment tax credits | 695 | | | 682 | | Deferred income taxes and unamortized investment tax credits | 742 | | | 734 | |
| Regulatory liabilities | Regulatory liabilities | 197 | | | 214 | | Regulatory liabilities | 148 | | | 156 | |
| | Non-pension postretirement benefit obligations | Non-pension postretirement benefit obligations | 10 | | | 12 | | Non-pension postretirement benefit obligations | 7 | | | 8 | |
| | Other | Other | 143 | | | 49 | | Other | 83 | | | 100 | |
| Total deferred credits and other liabilities | Total deferred credits and other liabilities | 1,045 | | | 957 | | Total deferred credits and other liabilities | 980 | | | 998 | |
| Total liabilities | Total liabilities | 3,305 | | | 2,981 | | Total liabilities | 3,185 | | | 3,226 | |
| Commitments and contingencies | Commitments and contingencies | 0 | | 0 | Commitments and contingencies | | | |
| Shareholder's equity | Shareholder's equity | | Shareholder's equity | |
| Common stock | Common stock | 1,763 | | | 1,590 | | Common stock | 1,828 | | | 1,765 | |
| Retained deficit | (16) | | | (15) | | |
| Retained earnings (deficit) | | Retained earnings (deficit) | — | | | (12) | |
| | Total shareholder's equity | Total shareholder's equity | 1,747 | | | 1,575 | | Total shareholder's equity | 1,828 | | | 1,753 | |
| Total liabilities and shareholder's equity | Total liabilities and shareholder's equity | $ | 5,052 | | | $ | 4,556 | | Total liabilities and shareholder's equity | $ | 5,013 | | | $ | 4,979 | |
See the Combined Notes to Consolidated Financial Statements
4847
ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY
(Unaudited)
| | | Six Months Ended June 30, 2022 | | Three Months Ended March 31, 2023 |
| (In millions) | (In millions) | Common Stock | | | Retained Deficit | | Total Shareholder's Equity | (In millions) | Common Stock | | | Retained (Deficit) Earnings | | Total Shareholder's Equity |
| Balance, December 31, 2021 | $ | 1,590 | | | | $ | (15) | | | $ | 1,575 | | |
| Balance, December 31, 2022 | | Balance, December 31, 2022 | $ | 1,765 | | | | $ | (12) | | | $ | 1,753 | |
| Net income | Net income | — | | | | 26 | | | 26 | | Net income | — | | | | 33 | | | 33 | |
| Common stock dividends | Common stock dividends | — | | | | (19) | | | (19) | | Common stock dividends | — | | | | (21) | | | (21) | |
| Contributions from parent | Contributions from parent | 173 | | | | — | | | 173 | | Contributions from parent | 63 | | | | — | | | 63 | |
| Balance, March 31, 2022 | $ | 1,763 | | | | $ | (8) | | | $ | 1,755 | | |
| Net income | — | | | | 11 | | | 11 | | |
| Common stock dividends | — | | | | (19) | | | (19) | | |
| Balance, March 31, 2023 | | Balance, March 31, 2023 | $ | 1,828 | | | | $ | — | | | $ | 1,828 | |
| | Balance, June 30, 2022 | $ | 1,763 | | | | $ | (16) | | | $ | 1,747 | | |
|
| | | Six Months Ended June 30, 2021 | | Three Months Ended March 31, 2022 |
| (In millions) | (In millions) | Common Stock | | | Retained Earnings (Deficit) | | Total Shareholder's Equity | (In millions) | Common Stock | | | Retained Deficit | | Total Shareholder's Equity |
| Balance, December 31, 2020 | $ | 1,271 | | | | $ | 127 | | | $ | 1,398 | | |
| Balance, December 31, 2021 | | Balance, December 31, 2021 | $ | 1,590 | | | | $ | (15) | | | $ | 1,575 | |
| Net income | Net income | — | | | | 14 | | | 14 | | Net income | — | | | | 26 | | | 26 | |
| Common stock dividends | Common stock dividends | — | | | | (14) | | | (14) | | Common stock dividends | — | | | | (19) | | | (19) | |
| Contributions from parent | Contributions from parent | 303 | | | | — | | | 303 | | Contributions from parent | 173 | | | | — | | | 173 | |
| Balance, March 31, 2021 | $ | 1,574 | | | | $ | 127 | | | $ | 1,701 | | |
| Net income | — | | | | 37 | | | 37 | | |
| Common stock dividends | — | | | | (215) | | | (215) | | |
| Balance, March 31, 2022 | | Balance, March 31, 2022 | $ | 1,763 | | | | $ | (8) | | | $ | 1,755 | |
| | Balance, June 30, 2021 | $ | 1,574 | | | | $ | (51) | | | $ | 1,523 | | |
|
See the Combined Notes to Consolidated Financial Statements
4948
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Dollars in millions, except per share data, unless otherwise noted)
Note 1 — Significant Accounting Policies
1. Significant Accounting Policies (All Registrants)
Description of Business
Exelon is a utility services holding company engaged in the energy distributiontransmission and transmissiondistribution businesses through ComEd, PECO, BGE, Pepco, DPL, and ACE.
On February 21, 2021, Exelon's Board of Directors approved a plan to separate the Utility Registrants and Generation. The separation was completed on February 1, 2022, creating two publicly traded companies, Exelon and Constellation. See Note 2 — Discontinued Operations for additional information.
| | | | | | | | | | | | | | |
| Name of Registrant | | Business | | Service Territories |
| Commonwealth Edison Company | | Purchase and regulated retail sale of electricity | | Northern Illinois, including the City of Chicago |
| | Transmission and distribution of electricity to retail customers | | |
| PECO Energy Company | | Purchase and regulated retail sale of electricity and natural gas | | Southeastern Pennsylvania, including the City of Philadelphia (electricity) |
| | Transmission and distribution of electricity and distribution of natural gas to retail customers | | Pennsylvania counties surrounding the City of Philadelphia (natural gas) |
| Baltimore Gas and Electric Company | | Purchase and regulated retail sale of electricity and natural gas | | Central Maryland, including the City of Baltimore (electricity and natural gas) |
| | Transmission and distribution of electricity and distribution of natural gas to retail customers | | |
| Pepco Holdings LLC | | Utility services holding company engaged, through its reportable segments Pepco, DPL, and ACE | | Service Territories of Pepco, DPL, and ACE |
| | | | |
Potomac Electric
Power Company | | Purchase and regulated retail sale of electricity | | District of Columbia, and major portions of Montgomery and Prince George’s Counties, Maryland |
| | Transmission and distribution of electricity to retail customers | | |
Delmarva Power &
Light Company | | Purchase and regulated retail sale of electricity and natural gas | | Portions of Delaware and Maryland (electricity) |
| | Transmission and distribution of electricity and distribution of natural gas to retail customers | | Portions of New Castle County, Delaware (natural gas) |
| Atlantic City Electric Company | | Purchase and regulated retail sale of electricity | | Portions of Southern New Jersey |
| | Transmission and distribution of electricity to retail customers | | |
Basis of Presentation
This is a combined quarterly report of all Registrants. The Notes to the Consolidated Financial Statements apply to the Registrants as indicated parenthetically next to each corresponding disclosure. When appropriate, the Registrants are named specifically for their related activities and disclosures. Each of the Registrant’s Consolidated Financial Statements includes the accounts of its subsidiaries. All intercompany transactions have been eliminated, except for the historical transactions between the Utility Registrants and Generation for the purposes of presenting discontinued operations in all periods presented in the Consolidated Statements of Operations and Comprehensive Income.
Through its business services subsidiary, BSC, Exelon provides its subsidiaries with a variety of support services at cost, including legal, human resources, financial, information technology, and supply management services. PHI also has a business services subsidiary, PHISCO, which provides a variety of support services at cost, including legal, accounting,finance, engineering, customer operations, distribution and transmission planning, asset management, system operations, and power procurement, to PHI operating companies. The costs of BSC and PHISCO are directly charged or allocated to the applicable subsidiaries. The results of Exelon’s corporate operations are presented as “Other” in the consolidated financial statements and include intercompany eliminations unless otherwise disclosed.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Dollars in millions, except per share data, unless otherwise noted)
Note 1 — Significant Accounting Policies
The accompanying consolidated financial statements as of June 30, 2022March 31, 2023 and for the three and six months ended June 30,March 31, 2023 and 2022 and 2021 are unaudited but, in the opinion of the management of each Registrant include all adjustments that are considered necessary for a fair statement of the Registrants’ respective financial statements in accordance with GAAP. All adjustments are of a normal, recurring nature, except as otherwise
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Dollars in millions, except per share data, unless otherwise noted)
Note 1 — Significant Accounting Policies
disclosed. The December 31, 20212022 Consolidated Balance Sheets were derived from audited financial statements. The interim financial statements are to be read in conjunction with prior annual financial statements and notes. Additionally, financial results for interim periods are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2022.2023. These Combined Notes to Consolidated Financial Statements have been prepared pursuant to the rules and regulations of the SEC for Quarterly Reports on Form 10-Q. Certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations.
The separation of Constellation, including Generation and its subsidiaries, meetsmet the criteria for discontinued operations and as such, results of operations are presented as discontinued operations and have been excluded from continuing operations for all periods presented. Accounting rules require that certain BSC costs previously allocated to Generation be presented as part of Exelon’s continuing operations as these costs do not qualify as expenses of the discontinued operations. Comprehensive income, shareholders' equity, and cash flows related to Constellation have not been segregated and are included in the Consolidated Statements of Operations and Comprehensive Income, Consolidated Statements of Changes in Shareholders’ Equity, and Consolidated Statements of Cash Flows, respectively, for all periods presented.the three months ended March 31, 2022. See Note 2 — Discontinued Operations for additional information.
2. Discontinued Operations (Exelon)
On February 21, 2021, Exelon's Board of Directors approved a plan to separate the Utility Registrants and Generation, creating two publicly traded companies ("the separation"). Exelon completed the separation on February 1, 2022, through the distribution of 326,663,937 common stock shares of Constellation, the new publicly traded company, to Exelon shareholders. Under the separation plan, Exelon shareholders retained their current shares of Exelon stock and received one share of Constellation common stock for every three shares of Exelon common stock held on January 20, 2022, the record date for the distribution, in a transaction that is tax-free to Exelon and its shareholders for U.S. federal income tax purposes.
2022. Constellation was newly formed and incorporated in Pennsylvania on June 15, 2021 for the purposes of separation and holds Generation (including Generation's subsidiaries).
Pursuant to the separation:
•Exelon entered into four term loans consisting of a 364-day term loan for $1.15 billion and three 18-month term loans for $300 million, $300 million and $250 million, respectively. Exelon issued these term loans primarily to fund the cash payment to Constellation and for general corporate purposes. See Note 10 — Debt and Credit Agreements for additional information.
•Exelon made a cash payment of $1.75 billion to Constellation on January 31, 2022.
•separation, Exelon contributed its equity ownership interest in Generation to Constellation. Exelon no longer retains any equity ownership interest in Generation or Constellation.
•Exelon transferred certain corporate assets and employee-related obligations to Constellation.
•Exelon received cash from Generation of $258 million to settle the intercompany loan on January 31, 2022. See Note 102 — Debt and Credit AgreementsDiscontinued Operations of the 2022 Form 10-K for additional information.
Continuing Involvement
In order to govern the ongoing relationships between Exelon and Constellation after the separation, and to facilitate an orderly transition, Exelon and Constellation have entered into several agreements, including the following:
•Separation Agreement – governs the rights and obligations between Exelon and Constellation regarding certain actions to be taken in connection with the separation, among others, including the allocation of assets and liabilities between Exelon and Constellation.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 2 — Discontinued Operations
•Transition Services Agreement (TSA) – governs the terms and conditions of the services that Exelon will provide to Constellation and Constellation will provide to Exelon for an expected period of two years, provided that certain services may be longer than the term and services may be extended with approval from both parties. The services include specified accounting, finance, information technology, human resources, employee benefits and other services that have historically been provided on a centralized basis by BSC. For the three months ended June 30,March 31, 2023, the amounts Exelon billed Constellation and Constellation billed Exelon for these services were $50 million recorded in Other income, net and $6 million recorded in Operating and maintenance expense, respectively. For the period from February 1, 2022 to March 31, 2022, the amounts Exelon billed Constellation and Constellation billed Exelon for these services were $69$56 million recorded in Other income, net and $11 million recorded in Operating and maintenance expense, respectively. Additionally, for the period from February 1, 2022 to June 30, 2022, the amounts Exelon billed Constellation and Constellation billed Exelon for these services were $125 million recorded in Other income, net and $20$9 million recorded in Operating and maintenance expense, respectively.
•Tax Matters Agreement (TMA) – governs the respective rights, responsibilities and obligations of Exelon and Constellation with respect to all tax matters, including tax liabilities and benefits, tax attributes, tax returns, tax contests and other tax sharing regarding U.S. federal, state, local and foreign income taxes, other tax matters and related tax returns. See Note 7.7 — Income Taxes for additional information.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 2 — Discontinued Operations
In addition, the Utility Registrants will continue to incur expenses from transactions with GenerationConstellation after the separation. Prior to the separation, such expenses were primarily recorded as Purchased power from affiliates and an immaterial amount recorded as Operating and maintenance expense from affiliates at the Utility Registrants. After the separation, such expenses are primarily recorded as Purchased power and an immaterial amount recorded as Operating and maintenance expense at the Utility Registrants.
•ComEd had an ICC-approved RFP contract with GenerationConstellation to provide a portion of ComEd’s electric supply requirements. ComEd also purchased RECs and ZECs from Generation.Constellation.
•PECO received electric supply from GenerationConstellation under contracts executed through PECO’s competitive procurement process. In addition, PECO had a ten-year agreement with GenerationConstellation to sell solar AECs.
•BGE received a portion of its energy requirements from GenerationConstellation under its MDPSC-approved market-based SOS and gas commodity programs.
•Pepco received electric supply from GenerationConstellation under contracts executed through Pepco’s competitive procurement process approved by the MDPSC and DCPSC.
•DPL received a portion of its energy requirements from GenerationConstellation under its MDPSC and DEPSC approved market-based SOS commodity programs.
•ACE received electric supply from GenerationConstellation under contracts executed through ACE’s competitive procurement process approved by the NJBPU.
ComEd and PECO also have receivables with Generation as a result of the nuclear decommissioning contractual construct whereby, to the extent NDTConstellation for estimated excess funds are greater than the underlying ARO at the end of decommissioning the Regulatory Agreement Units, such amounts are due back to ComEd and PECO, as applicable, for payment to their respective customers. See Note 93 — Asset Retirement Obligations of the Combined Notes to Consolidated Financial Statements of the 2021 Recast Form 10-KRegulatory Matters and Note 1523 — Related Party Transactions of the 2022 Form 10-K for additional information.
Discontinued Operations
The separation represented a strategic shift that would have a major effect on Exelon’s operations and financial results. Accordingly, the separation meets the criteria for discontinued operations.
There were no results from discontinued operations for the three months ended March 31, 2023. The following table presents the results of Constellation that have been reclassified from continuing operations and included in discontinued operations within Exelon’s Consolidated Statements of Operations and Comprehensive Income for the three and six months ended June 30, 2022 and June 30, 2021.March 31, 2022.
These results are primarily Generation, which is comprised of Exelon’s Mid-Atlantic, Midwest, New York, ERCOT, and Other Power Regions reportable segments, and include the impact of transaction costs, certain BSC costs, including any transition costs, that were historically allocated and directly attributable to Generation, transactions between Generation and the Utility Registrants, and tax-related adjustments. Transaction costs include costs for
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 2 — Discontinued Operations
external bankers, accountants, appraisers, lawyers, external counsels and other advisors, among others, who are involved in the negotiation, appraisal, due diligence and regulatory approval of the separation. Transition costs are primarily employee-related costs such as recruitment expenses, costs to establish certain stand-alone functions and information technology systems, professional services fees and other separation-related costs during the transition to separate Generation. For the purposes of reporting discontinued operations, these results also include transactions between Generation and the Utility Registrants that were historically eliminated within Exelon’s Consolidated Statements of Operations as these transactions will be ongoing after the separation. Certain BSC costs that were historically allocated to Generation are presented as part of continuing operations in Exelon’s Consolidated Statements of Operations as these costs do not qualify as expenses of the discontinued operations per the accounting rules.
| | | | | | | | | | | | | | | | | | | |
| | | Three Months Ended
June 30, | | Six Months Ended
June 30, |
| | | 2021 | | 2022 | | 2021 |
| Operating revenues | | | | | | | |
| Competitive business revenues | | | $ | 3,900 | | | $ | 1,855 | | | $ | 9,165 | |
| Competitive business revenues from affiliates | | | 255 | | | 161 | | | 549 | |
| Total operating revenues | | | 4,155 | | | 2,016 | | | 9,714 | |
| Operating expenses | | | | | | | |
| Competitive businesses purchased power and fuel | | | 1,947 | | | 1,138 | | | 6,557 | |
| | | | | | | |
Operating and maintenance(a) | | | 1,382 | | | 371 | | | 2,287 | |
| | | | | | | |
| Depreciation and amortization | | | 930 | | | 94 | | | 1,869 | |
| Taxes other than income taxes | | | 118 | | | 44 | | | 239 | |
| Total operating expenses | | | 4,377 | | | 1,647 | | | 10,952 | |
| Gain on sales of assets and businesses | | | 8 | | | 10 | | | 79 | |
| Operating income (loss) | | | (214) | | | 379 | | | (1,159) | |
| Other income and (deductions) | | | | | | | |
| Interest expense, net | | | (72) | | | (20) | | | (140) | |
| | | | | | | |
| Other, net | | | 508 | | | (281) | | | 675 | |
| Total other income and (deductions) | | | 436 | | | (301) | | | 535 | |
| Income (loss) before income taxes | | | 222 | | | 78 | | | (624) | |
| Income taxes | | | 71 | | | (40) | | | 13 | |
| Equity in losses of unconsolidated affiliates | | | (1) | | | (1) | | | (3) | |
| Net income (loss) | | | 150 | | | 117 | | | (640) | |
| Net income attributable to noncontrolling interests | | | 75 | | | 1 | | | 99 | |
| Net income (loss) from discontinued operations | | | $ | 75 | | | $ | 116 | | | $ | (739) | |
__________
(a)Includes transaction and transition costs related to the separation of $52 million for the six months ended June 30, 2022 and $4 million and $7 million for the three and six months ended June 30, 2021, respectively. See discussion above for additional information.
There were no assets and liabilities of discontinued operations included in Exelon’s Consolidated Balance Sheet as of June 30, 2022. Constellation had net assets of $11,573 million that separated on February 1, 2022 that resulted in a reduction to Exelon’s equity during the six months ended June 30, 2022. Refer to the Distribution of Constellation line in Exelon’s Consolidated Statement of Changes in Shareholders’ Equity for further information.
The following table presents the assets and liabilities of discontinued operations in Exelon’s Consolidated Balance Sheet as of December 31, 2021:
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 2 — Discontinued Operations
| | | | | | | |
| | | Three Months Ended
March 31, |
| | | December 31, 20212022 |
ASSETSOperating revenues | | | |
Current assetsCompetitive business revenues | | |
Cash and cash equivalents | | $ | 5101,855 | |
Restricted cash and cash equivalents | | 72 | |
Accounts receivableCompetitive business revenues from affiliates | | |
Customer accounts receivable | | 1,724 |
Customer allowance for credit losses | | (55) |
Customer accounts receivable, net | | 1,669 | |
Other accounts receivable | | 596 |
Other allowance for credit losses | | (4) |
Other accounts receivable, net | | 592 | |
Mark-to-market derivative assets | | 2,169 | |
Inventories, net | | |
Fossil fuel and emission allowances | | 284 | |
Materials and supplies | | 1,004 | |
Renewable energy credits | | 529 | |
Assets held for sale | | 13 | |
Other | | 993161 | |
Total current assets of discontinued operationsoperating revenues | | | 7,8352,016 | |
Property, plant, and equipment (net of accumulated depreciation and amortization of $15,888) | | 19,661 Operating expenses | |
Deferred debits and other assets | | |
Nuclear decommissioning trust fundsCompetitive businesses purchased power and fuel | | 15,938 | |
Investments | | 1931,138 | |
| | | |
Operating and maintenance(a) | | | 371 | |
| | | |
Mark-to-market derivative assetsDepreciation and amortization | | | 94994 | |
| Taxes other than income taxes | | | 44 | |
| Total operating expenses | | | 1,647 | |
| Gain on sales of assets and businesses | | | 10 | |
| Operating income | | | 379 | |
| Other income and (deductions) | | | |
1,768 Interest expense, net | | | (20) | |
| | | |
| Other, net | | | (281) | |
Total property, plant,other (deductions) and equipment, deferred debits, and other assets of discontinued operationsincome | | | 38,509 (301) | |
Total assetsIncome before income taxes | | | 78 | |
| Income taxes | | | (40) | |
| Equity in losses of unconsolidated affiliates | | | (1) | |
| Net income | | | 117 | |
| Net income attributable to noncontrolling interests | | | 1 | |
| Net income from discontinued operations | | | $ | 46,344116 | |
__________
(a)Includes transaction and transition costs related to the separation of $52 million for the three months ended March 31, 2022.
There were no assets or liabilities of discontinued operations included in Exelon's Consolidated Balance Sheet as of March 31, 2023 and December 31, 2022. Constellation had net assets of $11,573 million that separated on February 1, 2022 that resulted in a reduction to Exelon's equity during the year ended December 31, 2022. Refer to the Distribution of Constellation line in Exelon's Consolidated Statement of Changes in Shareholders' Equity for further information.
There were no discontinued operations included within Exelon’s Consolidated Statements of Cash Flows for the three months ended March 31, 2023. The following table presents selected financial information regarding cash flows of the discontinued operations that are included within Exelon’s Consolidated Statements of Cash Flows for the three months ended March 31, 2022.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 2 — Discontinued Operations
| | | | | |
| | Three Months Ended
March 31, |
| | December 31, 20212022 |
LIABILITIES AND SHAREHOLDERS’ EQUITYNon-cash items included in net income from discontinued operations: | | |
Current liabilitiesDepreciation, amortization, and accretion, including nuclear fuel and energy contract amortization | | |
Short-term borrowings | | $ | 2,082 | |
Long-term debt due within one year | | 1,220 | |
Accounts payable | | 1,757 | |
Accrued expenses | | 818 | |
Mark-to-market derivative liabilities | | 981207 | |
| | |
Renewable energy credit obligationLoss on sales of assets and businesses | | 7799 | |
Liabilities held for sale | | 3 | |
Other | | 300 | |
Total current liabilities of discontinued operations | | 7,940 | |
Long-term debt | | 4,575 | |
Deferred credits and other liabilities | | |
Deferred income taxes and unamortizedamortization of investment tax credits | | 3,583 (143) | |
Asset retirement obligationsNet fair value changes related to derivatives | | 12,819 (59) | |
Pension obligationsNet realized and unrealized losses on NDT fund investments | | 939205 | |
Non-pension postretirement benefit obligationsNet unrealized losses on equity investments | | 87616 | |
Spent nuclear fuel obligationOther decommissioning-related activity | | 1,21036 | |
Mark-to-market derivative liabilitiesCash flows from investing activities: | |
513Capital expenditures | (227) | |
| Collection of DPP | 169 | |
| Supplemental cash flow information: | |
| Decrease in capital expenditures not paid | (128) | |
| Increase in DPP | 348 | |
| Increase in PP&E related to ARO update | 335 | |
| | |
Other | | 1,161 | |
Total long-term debt, deferred credits, and other liabilities of discontinued operations | | 25,676 | |
Total liabilities of discontinued operations | | $ | 33,616 | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
| | |
3. Regulatory Matters (All Registrants)
As discussed in Note 3 — Regulatory Mattersof the 2022 Form 10-K, the Registrants are involved in rate and regulatory proceedings at FERC and their state commissions. The following discusses developments in 2023 and updates to the 2022 Form 10-K.
Distribution Base Rate Case Proceedings
The following table presents selected financial information regarding cash flows oftables show the discontinued operations that are included within Exelon’s Consolidated Statements of Cash Flows for the six months ended June 30, 2022completed and June 30, 2021.pending distribution base rate case proceedings in 2023.
| | | | | | | | | | | |
| Six Months Ended
June 30, |
| 2022 | | 2021 |
| Non-cash items included in net income (loss) from discontinued operations: | | | |
| Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization | $ | 207 | | | $ | 2,686 | |
| Asset impairments | — | | | 493 | |
| Gain on sales of assets and businesses | 9 | | | (79) | |
| Deferred income taxes and amortization of investment tax credits | (143) | | | (268) | |
| Net fair value changes related to derivatives | (59) | | | (490) | |
| Net realized and unrealized losses (gains) on NDT fund investments | 205 | | | (376) | |
| Net unrealized losses (gains) on equity investments | 16 | | | (96) | |
| Other decommissioning-related activity | 36 | | | (636) | |
| Cash flows from investing activities: | | | |
| Capital expenditures | (227) | | | (731) | |
| Collection of DPP | 169 | | | 2,209 | |
| Supplemental cash flow information: | | | |
| Decrease in capital expenditures not paid | (128) | | | (66) | |
| Increase in DPP | 348 | | | 1,958 | |
| Increase in PP&E related to ARO update | 335 | | | — | |
| | | |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 3 — Regulatory Matters
3. Regulatory Matters (All Registrants)
As discussed in Note 3 — Regulatory Matters of the 2021 Recast Form 10-K, the Registrants are involved in rate and regulatory proceedings at FERC and their state commissions. The following discusses developments in 2022 and updates to the 2021 Recast Form 10-K.
Distribution Base Rate Case Proceedings
The following tables show the completed and pending distribution base rate case proceedings in 2022.
Completed Distribution Base Rate Case Proceedings
| | Registrant/Jurisdiction | Registrant/Jurisdiction | | Filing Date | | Service | | Requested Revenue Requirement Increase | | Approved Revenue Requirement Increase | | Approved ROE | | Approval Date | | Rate Effective Date | Registrant/Jurisdiction | | Filing Date | | Service | | Requested Revenue Requirement Increase | | Approved Revenue Requirement Increase | | Approved ROE | | Approval Date | | Rate Effective Date |
ComEd - Illinois(a) | ComEd - Illinois(a) | | April 16, 2021 | | Electric | | $ | 51 | | | $ | 46 | | | 7.36 | % | | December 1, 2021 | | January 1, 2022 | ComEd - Illinois(a) | | April 15, 2022 | | Electric | | $ | 199 | | | $ | 199 | | | 7.85 | % | | November 17, 2022 | | January 1, 2023 |
| PECO - Pennsylvania | PECO - Pennsylvania | | March 30, 2021 | | Electric | | 246 | | | 132 | | | N/A(b) | | November 18, 2021 | | January 1, 2022 | PECO - Pennsylvania | | March 31, 2022 | | Natural Gas | | 82 | | | 55 | | | N/A(b) | | October 27, 2022 | | January 1, 2023 |
BGE - Maryland(c) | BGE - Maryland(c) | | May 15, 2020 (amended September 11, 2020) | | Electric | | 203 | | | 140 | | | 9.50 | % | | December 16, 2020 | | January 1, 2021 | BGE - Maryland(c) | | May 15, 2020 (amended September 11, 2020) | | Electric | | 203 | | | 140 | | | 9.50 | % | | December 16, 2020 | | January 1, 2021 |
| Natural Gas | | 108 | | | 74 | | | 9.65 | % | | | Natural Gas | | 108 | | | 74 | | | 9.65 | % | |
Pepco - District of Columbia(d) | | May 30, 2019 (amended June 1, 2020) | | Electric | | 136 | | | 109 | | | 9.275 | % | | June 8, 2021 | | July 1, 2021 | |
| Pepco - Maryland(e)(d) | Pepco - Maryland(e)(d) | | October 26, 2020 (amended March 31, 2021) | | Electric | | 104 | | | 52 | | | 9.55 | % | | June 28, 2021 | | June 28, 2021 | Pepco - Maryland(e)(d) | | October 26, 2020 (amended March 31, 2021) | | Electric | | 104 | | | 52 | | | 9.55 | % | | June 28, 2021 | | June 28, 2021 |
DPL - Maryland(f)(e) | DPL - Maryland(f)(e) | | September 1, 2021 (amended December 23, 2021) | | Electric | | 27 | | | 13 | | | 9.60 | % | | March 2, 2022 | | March 2, 2022 | DPL - Maryland(f)(e) | | May 19, 2022 | | Electric | | 38 | | | 29 | | | 9.60 | % | | December 14, 2022 | | January 1, 2023 |
ACE - New Jersey(g) | | December 9, 2020 (amended February 26, 2021) | | Electric | | 67 | | | 41 | | | 9.60 | % | | July 14, 2021 | | January 1, 2022 | |
|
__________
(a)ComEd's 20222023 approved revenue requirement above reflects an increase of $37$144 million for the initial year revenue requirement for 20222023 and an increase of $9$55 million related to the annual reconciliation for 2020.2021. The revenue requirement for 20222023 provides for a weighted average debt and equity return on distribution rate base of 5.72%5.94%, inclusive of an allowed ROE of 7.36%7.85%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points. The reconciliation revenue requirement for 20202021 provides for a weighted average debt and equity return on distribution rate base of 5.69%5.91%, inclusive of an allowed ROE of 7.29%7.78%, reflecting the monthly yields on 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points.This is ComEd's last performance-based electric distribution formula rate update filing under EIMA. See discussion of CEJA below for details on the transition away from the electric distribution formula rate.
(b)The PECO electricnatural gas base rate case proceeding was resolved through a settlement agreement, which did not specify an approved ROE.
(c)Reflects a three-year cumulative multi-year plan for 2021 through 2023. BGE proposed to use certain tax benefits to fully offset the increases in 2021 and 2022 and partially offset the increase in 2023. The MDPSC awarded BGE electric revenue requirement increases of $59 million, $39 million, and $42 million, before offsets, in 2021, 2022, and 2023, respectively, and natural gas revenue requirement increases of $53 million, $11 million, and $10 million, before offsets, in 2021, 2022, and 2023, respectively. BGE proposed to use certain tax benefits to fully offset the increases in 2021 and 2022 and partially offset the increase in 2023. However, the MDPSC utilized the tax benefits to fully offset the increases in 2021 and January 2022 such that customer rates remained unchanged. For the remainder of 2022, the MDPSC chose to offset only 25% of the cumulative 2021 and 2022 electric revenue requirement increases and 50% of the cumulative gas revenue requirement increases. WhetherIn 2021, the MDPSC deferred a decision on whether to use certain tax benefits willto offset the revenue requirement increases in 2023 and directed BGE to make another proposal at the end of 2022. In September 2022 BGE proposed that tax benefits not be used to offset the customer rate increases in 2023 hasrevenue requirement increases. On October 26, 2022, the MDPSC accepted BGE's recommendation to not been decided, and BGE cannot predictuse tax benefits to offset the outcome.2023 revenue requirement increases.
(d)Reflects a cumulative multi-year plan with 18-months remaining in 2021 through 2022. The DCPSC awarded Pepco electric incremental revenue requirement increases of $42 million and $67 million, before offsets, for 2021 and 2022, respectively. However, the DCPSC utilized the acceleration of refunds for certain tax benefits along with other rate relief to partially offset the customer rate increases by $22 million and $40 million for 2021 and 2022, respectively.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 3 — Regulatory Matters
(e)Reflects a three-year cumulative multi-year plan for April 1, 2021 through March 31, 2024. The MDPSC awarded Pepco electric incremental revenue requirement increases of $21 million, $16 million, and $15 million, before offsets, for the 12-month periods ending March 31, 2022, 2023, and 2024, respectively. Pepco proposed to utilize certain tax benefits to fully offset the increase through 2023 and partially offset customer rate increases in 2024. However, the MDPSC only utilized the acceleration of refunds for certain tax benefits to fully offset the increases such that customer rates remain unchanged through March 31, 2022. On February 23, 2022, the MDPSC chose to offset 25% of the cumulative revenue requirement increase for the 12-month period ending March 31, 2023. Whether certain tax benefits will be used to offset the customer rate increases for the 12-month period ending March 31, 2024 has not been decided, and Pepco cannot predict the outcome.
(f)(e)Reflects a three-year cumulative multi-year plan for January 1, 2023 through December 31, 2025. The approved settlement reflects a 9.60% ROE, which is solelyMDPSC awarded DPL electric incremental revenue requirement increases of $17 million, $6 million, and $6 million for the purposes of calculating AFUDC2023, 2024, and regulatory asset carrying costs.2025, respectively.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS Requested and approved increases are before New Jersey sales and use tax. The order allows ACE to retain approximately $11 million of certain tax benefits which resulted— (Continued)
(Dollars in a decrease to income tax expense in Exelon's, PHI's, and ACE's Consolidated Statements of Operations and Comprehensive Income in the third quarter of 2021.millions, except per share data, unless otherwise noted)
Note 3 — Regulatory Matters
Pending Distribution Base Rate Case Proceedings
| | Registrant/Jurisdiction | Registrant/Jurisdiction | | Filing Date | | Service | | Requested Revenue Requirement Increase | | Requested ROE | | Expected Approval Timing | Registrant/Jurisdiction | | Filing Date | | Service | | Requested Revenue Requirement Increase | | Requested ROE | | Expected Approval Timing |
ComEd - Illinois(a) | ComEd - Illinois(a) | | April 15, 2022 | | Electric | | $ | 199 | | | 7.85 | % | | Fourth quarter of 2022 | ComEd - Illinois(a) | | January 17, 2023 | | Electric | | $ | 1,472 | | | 10.50% to 10.65% | | Fourth quarter of 2023 |
| | PECO - Pennsylvania | | March 31, 2022 | | Natural Gas | | 82 | | | 10.95 | % | | Fourth quarter of 2022 | |
| ComEd - Illinois(b) | | ComEd - Illinois(b) | | April 21, 2023 | | Electric | | 247 | | | 8.91% | | Fourth quarter of 2023 |
BGE - Maryland(c) | | BGE - Maryland(c) | | February 17, 2023 | | Electric | | 313 | | | 10.40% | | Fourth quarter of 2023 |
| Natural Gas | 289 | | | 10.40% |
Pepco - District of Columbia(d) | | Pepco - District of Columbia(d) | | April 13, 2023 | | Electric | | 191 | | | 10.50% | | First quarter of 2024 |
DPL - Delaware(b)(e) | DPL - Delaware(b)(e) | | January 14, 2022 (amended February 28, 2022) | | Natural Gas | | 15 | | | 10.30 | % | | First quarter of 2023 | DPL - Delaware(b)(e) | | December 15, 2022 (amended February 28, 2023) | | Electric | | 48 | | | 10.50% | | Second quarter of 2024 |
DPL - Maryland(c) | | May 19, 2022 | | Electric | | 38 | | | 10.25 | % | | Fourth quarter of 2022 | |
| ACE - New Jersey(f) | | ACE - New Jersey(f) | | February 15, 2023 | | Electric | | 105 | | | 10.50% | | First quarter of 2024 |
(a)ComEd's 2023Reflects a four-year cumulative MRP for January 1, 2024 to December 31, 2027 and total requested revenue requirement reflects an increaseincreases of $144$877 million for the initial yeareffective January 1, 2024, $175 million effective January 1, 2025, $217 million effective January 1, 2026, and $203 million effective January 1, 2027, based on forecasted revenue requirement for 2023 and an increase of $55 million related to the annual reconciliation for 2021.requirements. The revenue requirement for 2023 provideswill provide for a weighted average debt and equity return on distribution rate base of 5.94%,7.43% in 2024, 7.50% in 2025, 7.62% in 2026, and 7.70% in 2027, inclusive of an allowed ROE of 7.85%, reflecting the average monthly yields for 30-year treasury bonds plus 580 basis points.10.50% in 2024, 10.55% in 2025, 10.60% in 2026, and 10.65% in 2027. The reconciliationrequested revenue requirement for 2021 provides forrequirements are based on capital structures that reflect between 50.58% and 51.19% common equity. ComEd’s MRP also includes a weighted average debt and equity return on distributionproposed rate base of 5.91%, inclusive of an allowed ROE of 7.78%, reflecting the average monthly yields for 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points. This is ComEd's last performance-based electric distribution formula rate update filing under EIMA as a resultphase-in to defer approximately $307 million of the law authorizing the rate setting process sunsetting at the end of 2022. See Note 3 - Regulatory Matters of the 2021 Recast Form 10-K$877 million year-over-year increase for additional information on ComEd's transition away2024 revenue from the electric distribution formula rate.2024 to 2026.
(b)On April 21, 2023, ComEd filed its proposed Delivery Reconciliation Amount of $247 million under Rider Delivery Service Pricing Reconciliation (Rider DSPR) which allows for the reconciliation of the revenue requirement in effect in the final years in which formula rates are determined and until such time as new rates are established under ComEd’s approved MRP. The 2023 filing reconciles the delivery service rates in effect in 2022 with the actual delivery service costs incurred in 2022. Final order is expected by December 2023, and the reconciliation amount will go into effect on August 14, 2022, subject to refund.be in customer rates beginning January 1, 2024.
(c)Reflects a three-year cumulative multi-year plan for January 1, 2023 to2024 through December 31, 2026 submitted to the MDPSC. Inclusive of the proposed acceleration of remaining electric tax benefits in 2024 and 2025, and remaining gas tax benefits in 2024, BGE requested total requestedelectric revenue requirement increases before offsets, of $23$85 million, effective January 1, 2023, $8$103 million, effective January 1,and $125 million in 2024, 2025, and $72026, respectively, and natural gas revenue requirement increases of $158 million, effective January 1,$77 million, and $54 million in 2024, 2025, and 2026, respectively. Requested revenue requirement increases will be used to recover capital investments made indesigned to increase the resilience of the electric and gas distribution systems and support Maryland’s climate and regulatory initiatives. The 2021 and planned2022 reconciliation amounts are not included in the requested revenue requirement increase, as BGE is proposing that these amounts be recovered through the separate electric and gas riders in 2024. The 2021 reconciliation amounts are $11 million and $7 million for electric and gas, respectively, and the 2022 reconciliation amounts are $44 million and $15 million for electric and gas, respectively.
(d)Reflects a three-year cumulative multi-year plan for January 1, 2024 through December 31, 2026 submitted to the DCPSC. Pepco requested total electric revenue requirement increases of $117 million, $37 million, and $37 million in 2024, 2025, and 2026, respectively. Requested revenue requirement increases will be used to recover capital investments throughdesigned to advance system-readiness and support the endDistrict of 2025. DPL is proposing the acceleration of refunds for certain tax benefitsColumbia’s climate and clean energy goals.
(e)The rates will go into effect on July 15, 2023, subject to partially offset the customer raterefund.
(f)Requested increases by $12 millionare before New Jersey sales and $8 million inuse tax. ACE intends to put rates into effect on November 17, 2023, and 2024, respectively.subject to refund.
Transmission Formula Rates
The Utility Registrants' transmission rates are each established based on a FERC-approved formula. ComEd, BGE, Pepco, DPL, and ACE are required to file an annual update to the FERC-approved formula on or before May 15, and PECO is required to file on or before May 31, with the resulting rates effective on June 1 of the same year. The annual update for ComEd is based on prior year actual costs and current year projected capital additions (initial year revenue requirement). The update for ComEd also reconciles any differences between the revenue requirement in effect beginning June 1 of the prior year and actual costs incurred for that year (annual reconciliation). The annual update for PECO is based on prior year actual costs and current year projected capital additions, accumulated depreciation, and accumulated deferred income taxes. The annual update for BGE Pepco, DPL, and ACE is based on prior year actual costs and current year projected capital additions, accumulated depreciation, depreciation and amortization expense, and accumulated deferred income taxes. The update for PECO, BGE, Pepco, DPL, and ACE also reconciles any differences between the actual costs and actual revenues for the calendar year (annual reconciliation).
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 3 — Regulatory Matters
taxes. The update for BGE also reconciles any differences between the actual costs and actual revenues for the calendar year (annual reconciliation).
For 2022,2023, the following total increases/(decreases) were included in the Utility Registrants'BGE's annual electric transmission formula rate update:updates. ComEd, PECO, Pepco, DPL, and ACE intend to file by the required deadline for the annual update.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
Registrant(a) | | Initial Revenue Requirement Increase | | Annual Reconciliation (Decrease) Increase | | Total Revenue Requirement Increase | | Allowed Return on Rate Base(b) | | Allowed ROE(c) |
| ComEd | | $ | 24 | | | $ | (24) | | | $ | — | | | 8.11 | % | | 11.50 | % |
| PECO | | 23 | | | 16 | | | 39 | | | 7.30 | % | | 10.35 | % |
| BGE | | 25 | | | (4) | | | 16 | | (d) | 7.30 | % | | 10.50 | % |
| Pepco | | 16 | | | 15 | | | 31 | | | 7.60 | % | | 10.50 | % |
| DPL | | 9 | | | 2 | | | 11 | | | 7.09 | % | | 10.50 | % |
| ACE | | 21 | | | 13 | | | 34 | | | 7.18 | % | | 10.50 | % |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
Registrant(a) | | Initial Revenue Requirement Increase | | Annual Reconciliation Decrease | | Total Revenue Requirement Increase | | Allowed Return on Rate Base(b) | | Allowed ROE(c) |
| | | | | | | | | | |
| | | | | | | | | | |
| BGE | | $ | 19 | | | $ | (12) | | | $ | 4 | | (d) | 7.34 | % | | 10.50 | % |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
__________
(a)All rates are effective June 1, 20222023 - May 31, 2023,2024, subject to review by interested parties pursuant to review protocols of each Utility Registrants' tariff.tariffs.
(b)Represents the weighted average debt and equity return on transmission rate bases. For ComEd and PECO, the common equity component of the ratio used to calculate the weighted average debt and equity return on the transmission formula rate base is currently capped at 55% and 55.75%, respectively.
(c)The rate of return on common equity for each Utility Registrant includes a 50-basis-point incentive adder for being a member of a RTO.
(d)The increase in BGE's transmission revenue requirement includes a $5$3 million reduction related to a FERC-approved dedicated facilities charge to recover the costs of providing transmission service to specifically designated load by BGE.
Other State Regulatory Matters
Illinois Regulatory Matters
CEJA (Exelon and ComEd). On September 15, 2021, the Governor of Illinois signed into law CEJA. CEJA includes, among other features, (1) procurement of CMCs from qualifying nuclear-powered generating facilities, (2) a requirement to file a general rate case or a new four-year multi-year planMRP no later than January 20, 2023 to establish rates effective after ComEd’s existing performance-based distribution formula rate sunsets, (3) an extension of and certain adjustments to ComEd’s energy efficiency MWh savings goals, (4) revisions to the Illinois RPS requirements, including expanded charges for the procurement of RECs from wind and solar generation, (5) a requirement to accelerate amortization of ComEd’s unprotected excess deferred income taxes ("EDIT")(EDIT) that ComEd was previously directed by the ICC to amortize using the average rate assumption method which equates to approximately 39.5 years, and (6) requirements that ComEd and the ICC initiate and conduct various regulatory proceedings on subjects including ethics, spending, grid investments, and performance metrics. Regulatory or legal challenges regarding the validity or implementation of CEJA are possible and Exelon and ComEd cannot reasonably predict the outcome of any such challenges.
ComEd Electric Distribution Rates
ComEd filed, and received approval for, its last performance-based electric distribution formula rate update filing under EIMA in 2022; those rates are in effect throughout 2023.
On February 3, 2022, the ICC approved a tariff that establishes the process under which ComEd will reconcile its 2022 and 2023 rate year revenue requirements with actual costs. Those reconciliation amounts will be determined using the same process as were used for prior reconciliations under the performance-based electric distribution formula rate. Using that process, for the rate years 2022 and 2023 ComEd will ultimately collect revenues from customers reflecting each year’s actual recoverable costs, year-end rate base, and a weighted average debt and equity return on distribution rate base, with the ROE component based on the annual average of the monthly yields of the 30-year U.S. Treasury bonds plus 580 basis points. In April 2023, ComEd filed its first petition with the ICC to reconcile its 2022 actual costs with the approved revenue requirement that was in effect in 2022. The rate year 2023 reconciliation will be filed in 2024.
Beginning in 2024, ComEd will recover from retail customers, subject to certain exceptions, the costs it incurs to provide electric delivery services either through its electric distribution rate or other recovery mechanisms authorized by CEJA. On January 17, 2023, ComEd filed a petition with the ICC seeking approval of a MRP for 2024-2027. The MRP supports a multi-year grid plan (Grid Plan), also filed on January 17, covering planned investments on the electric distribution system within ComEd’s service area through 2027. Costs incurred during each year of the MRP are subject to ICC review and the plan’s revenue requirement for each year will be reconciled with the actual costs that the ICC determines are prudently and reasonably incurred for that year. The reconciliation is subject to adjustment for certain costs, including a limitation on recovery of costs that are more than 105% of certain costs in the previously approved MRP revenue requirement, absent a modification of the
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 3 — Regulatory Matters
rate plan itself. Thus, for example, the rate adjustments necessary to reconcile 2024 revenues to ComEd’s actual 2024 costs incurred would take effect in January 2026 after the ICC’s review during 2025. The ICC must issue its decision on both the MRP and Grid Plan by mid-December 2023, for rates to begin with the January 2024 billing cycle.
In January 2022, ComEd filed a request with the ICC proposing performance metrics that would be used in determining ROE incentives and penalties in the event ComEd filed a MRP in January 2023. On September 27, 2022, the ICC issued a final order approving seven performance metrics that provide symmetrical performance adjustments of 32 total basis points to ComEd’s rate of return on common equity based on the extent to which ComEd achieves the annual performance goals. On November 10, 2022, the ICC granted ComEd's application for rehearing, in part. On April 5, the ICC issued its final order on rehearing for the performance and tracking metrics proceeding, in which the ICC declined to adopt ComEd’s proposed modifications to the reliability and peak load reduction performance metrics. ComEd is determining how to implement the performance metrics, which take effect on January 1, 2024. ComEd will make its initial filing in 2025 to assess performance achieved under the metrics in 2024, and to determine any ROE adjustment, which would take effect in 2026.
Carbon Mitigation Credit
CEJA establishes decarbonization requirements for Illinois as well as programs to support the retention and development of emissions-free sources of electricity. ComEd is required to purchase CMCs from participating nuclear-powered generating facilities between June 1, 2022 and May 31, 2027 and all its costs of doing so will be recovered through a new rider.2027. The price to be paid for each CMC was established through a competitive bidding process that included consumer-protection measures that capped the maximum acceptable bid amount and a formula that reduces CMC prices by an energy price index, the base residual auction capacity price in the ComEd zone of PJM, and the monetized value of any federal tax credit or other subsidy if applicable. The consumer protection measures contained in CEJA will result in net payments to ComEd ratepayers if the energy index, the capacity price and applicable federal tax credits or subsidy exceed the CMC contract price. ComEd began issuing credits to its retail customers under its new CMC rider in the June 2022 billing period and recorded a regulatory asset of $255$1,118 million as of June 30, 2022March 31, 2023 for the difference between customer credits issued and the credit to be received from the participating nuclear plants.nuclear-powered generating facilities.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 3 — Regulatory Matters
Excess Deferred Income Taxes
procuring CMCs, including carrying costs, will be recovered through a rider, the Rider Carbon-Free Resource Adjustment (Rider CFRA). The ICC initiated a docketRider CFRA provides for an annual reconciliation and true-up to accelerate and fully creditactual costs incurred or credits received by ComEd to customers TCJA unprotected property-related EDIT no later than December 31, 2025. On July 7, 2022, the ICC issued a final order on the schedule for the acceleration of EDIT amortization, adopting the proposal as submitted by several parties, including ComEd, ICC Staff, the Illinois Attorney General's Office, and the Citizens Utility Board. EDIT amortization willpurchase CMCs, with any difference to be credited to or collected from ComEd’s retail customers throughin subsequent periods. The difference between the net payments to (or receivables from) ComEd ratepayers and the credits received by ComEd to purchase CMCs is recorded to Purchased Power expense with an offset to the regulatory asset (or regulatory liability). On December 21, 2022, ComEd filed a new rider fromsupplemental statement to the Rider CFRA proposing that the company recover costs or provide credits faster than the tariff allows, implement monthly reconciliations, and allow the Company to adjust Rider CFRA rates based not only on anticipated differences but also past payments or credits. The ICC approved the proposal on January 1, 2023 through December 31, 2025.19, 2023.
Beneficial Electrification Plan
On July 1, 2022, ComEd filed a proposed plan to promote beneficial electrification efforts in its Northern Illinois service area with the ICC as required by CEJA. ComEd's plan is designed to meaningfully reduce barriers to beneficial electrification, including those related to electric vehicles (EV), such as upfront technology adoption costs, charging costs, and charging availability; promote equity and environmental justice; reduce carbon emissions and surface-level pollutants; and support customer education and awareness of electrification options. As proposed, ComEd could expend approximately $300 million in total over the three-year period 2023 through 2025. The beneficial electrification plan requests recovery of all those costs through a rider mechanism, under which certain of the costs would be amortized over ten years with a return on the unrecovered balance. An order is expectedOn November 10, 2022, in responses to be issued bya Staff motion, the ICC no later thanapproved an interim order dismissing from ComEd’s Beneficial Electrification Plan certain rebates (rebates to support residential customers’ purchase of EVs; and rebates to ComEd’s commercial and industrial customers to support the first quarterinstallation of 2023. At this time,EV chargers). However, the ICC found that building electrification measures were properly within the scope of beneficial electrification, in line with ComEd’s proposal. The ICC also adopted ComEd’s position regarding the rate impact of spending associated with EV related infrastructure. On November 21, 2022, ComEd cannot predictfiled an application for rehearing of the outcomeinterim order, which the ICC denied. On December 9, 2022, the Office of these proceedings.the Illinois Attorney General (AG) also
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 3 — Regulatory Matters
sought rehearing. On December 15, 2022, ComEd filed an appeal of the 2021 Recast Form 10-KICC’s interim order and the denial of rehearing with the Illinois Appellate Court. That appeal has been stayed pending the ICC's disposition of the case. Also on December 15, 2022, the ICC denied the AG’s application for additional information on CEJA (referredrehearing and the AG subsequently filed an appeal.
On March 23, 2023, the ICC issued its final order in the beneficial electrification plan docket. The order adopts the beneficial electrification plan with modifications and directs ComEd to seek cost recovery through the multi-year rate plan filing for 2024 and 2025, and the final formula rate reconciliation docket for 2023, rather than through a new rider beneficial electrification as Clean Energy Law).
Energy Efficiency Formula Rate (ExelonComEd had proposed. The order also rejects ComEd’s request for a regulatory asset. The order approves an overall annual budget of $77 million per year for each of the three years in the plan (2023 through 2025), with flexibility to roll forward unused funds to future years within the same plan period. The final order also made specific reductions to the proposed $100 million per year budget, reducing the proposed customer education and ComEd). awareness budget; the portfolio budget for cross-cutting administrative support; and the light, medium, and heavy-duty EV rebate programs. The order dedicates funds for rebates related to the installation of heat pumps and the promotion of home electrification for low-income customers and those in Environmental Justice and Restore, Reinvest, and Renew designated communities. The order also requires ComEd to propose methods to minimize or exempt low-income ratepayers from the impact of its beneficial electrification plan, possibly through ComEd’s next rate design investigation. On April 18, 2023, ComEd filed its annual energy efficiency formulaan application for rehearing concerning aspects of the ICC’s order, including the approved budgets. The ICC must act on that application by May 8, 2023. On April 21, 2023 the Chicago Transit Authority and city of Chicago jointly filed an application for rehearing requesting the ICC modify the final order so the transit agencies do not pay the cost of make-ready infrastructure and to exempt transit agencies from paying the required deposit or providing a letter of credit to ComEd for the cost of make-ready infrastructure. On April 24, 2023, the AG also filed an application for rehearing on several topics, including the budget, rebate levels, retail rate updatecap, types of programs included in the beneficial electrification plan, compliance with the EV Act, benefit-to-cost analysis, and rate-related issues. On April 27, 2023, ICC on May 25, 2022. The filing establishes the revenue requirement used to set the rates that will take effect in January 2023 after the ICC's review and approval. The requested revenue requirement update is based onstaff filed a reconciliationmotion for clarification of the 2021 actual costs plus projectedorder’s language regarding the annual budget. The ICC will likely rule on all of the applications for rehearing and staff’s motion at their regularly scheduled May 4, 2023 expenditures.
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Initial Revenue Requirement Increase | | Annual Reconciliation Decrease | | Total Revenue Requirement Increase | | Requested Return on Rate Base(a) | | Requested ROE |
| $ | 66 | | | $ | (16) | | | $ | 50 | | | 5.94 | % | | 7.85 | % |
__________
(a)The requested revenue requirement increase provides for a weighted average debt and equity return onregular open meeting. If the energy efficiency regulatory asset and rate base of 5.94% inclusive of an allowed ROE of 7.85%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points. For the 2021 reconciliation year, the requested revenue requirement provides for a weighted average debt and equity return on the energy efficiency regulatory asset and rate base of 5.52% inclusive of an allowed ROE of 6.99%, which includes a downward performance adjustment that decreased the ROE. The performance adjustment can either increase or decrease the ROE based upon the achievement of energy efficiency savings goals.ICC denies rehearing, parties have 35 days to appeal arguments raised in their rehearing applications.
New Jersey Regulatory Matters
Termination of Energy Procurement Provisions of PPAs (Exelon, PHI, and ACE).
On December 22, 2021, ACE filed with the NJBPU a petition to terminate the provisions in the PPAs to purchase electricity from two coal-powered generation facilities located in the state of New Jersey. The petition was approved by the NJBPU on March 23, 2022. Upon closing of the transaction on March 31, 2022, ACE recognized a liability of $203 million for the contract termination fee, which is to be paid by the end of 2024, and recognized a corresponding regulatory asset of $203 million.
As of June 30, 2022,March 31, 2023, the $180$118 million liability for the contract termination fee consists of $87 million and $93$31 million included in Other current liabilities and Other deferred credits and other liabilities, respectively, in Exelon's Consolidated Balance Sheet. The current and noncurrent liability isliabilities are included in PPA termination obligation and Other deferred credits and other liabilities, respectively, in PHI's and ACE's Consolidated Balance Sheets. For the sixthree months ended June 30, 2022,March 31, 2023, ACE has paid $23$19 million of the liability, which is recorded in Changes in Other assets and liabilities in Exelon's, PHI's, and ACE's Consolidated Statements of Cash Flows.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 3 — Regulatory Matters
Other Federal Regulatory Matters
FERC Audit (Exelon and ComEd). The Utility Registrants are subject to periodic audits by FERC. FERC’s Division of Audits and Accounting initiated a nonpublic audit of ComEd in May 2021 evaluating ComEd’s compliance with (1) approved terms, rates and conditions of its federally regulated service; (2) accounting requirements of the Uniform System of Accounts; (3) reporting requirements of the FERC Form 1; and (4) the requirements for record retention. The audit covered the period from January 1, 2017 through August 31, 2022. On January 17 and February 21, 2023, ComEd was provided with information on a series of potential findings, including concerning ComEd's methodology regarding the allocation of certain overhead costs to capital under FERC regulations. As of March 31, 2023, ComEd has continued discussions with FERC staff and determined that a loss is probable and has recorded a liability that reflects management's best estimate. The final outcome and resolution of the findings or of the audit itself cannot be predicted and the results could be material to the Exelon and ComEd financial statements.
Regulatory Assets and Liabilities
The Utility Registrants' regulatory assets and liabilities have not changed materially since December 31, 2021,2022, unless noted below. See Note 3 — Regulatory Mattersof the 2021 Recast2022 Form 10-K for additional information on the specific regulatory assets and liabilities.
ComEdComEd. . Regulatory assets increased $254$547 million primarily due to an increaseincreases of $255$275 million in the CMC regulatory asset, as discussed in CEJA above, $89and $143 million in the Electric Distribution Formula Rate Annual Reconciliations regulatory asset, and $29 million in the Energy Efficiency Costs regulatory asset partially offset by a decrease of $116 million in the Renewable Energy regulatory asset. Regulatory liabilities decreased $617 million primarily due to a decrease of $788 million in the Decommissioning the Regulatory Agreement Units regulatory liability and $45 million in the Deferred Income Taxes regulatory liability partially offset by an increase of $162 million in the Renewable Portfolio Standards Costs regulatory liability and $33 million in the Removal Costs regulatory liability.
PECO. Regulatory assets increased $103$44 million primarily due to an increase of $99$48 million in the Deferred Income Taxes regulatory asset. Regulatory liabilities decreased $325increased $45 million primarily due to a decreaseincreases of $305 million in the Decommissioning the Regulatory Agreement Units regulatory liability and $12$31 million in the Electric Energy and Natural Gas Costs regulatory liability and $28 million in the Decommissioning the Regulatory Agreement Units regulatory liability.
BGE. Regulatory assets increased $66 million primarily due to an increase of $54 million in the Under-Recovered Revenue Decoupling regulatory asset.
DPL. Regulatory assets decreased $49$17 million primarily due to a decrease of $20 million in the Under-recovered revenue decoupling regulatory asset, $14$18 million in the Electric Energy and Natural Gas Costs regulatory asset, and $13 million in the Energy Efficiency and Demand Response Programs regulatory asset.
Pepco.ACE. Regulatory assets decreased $47$18 million primarily due to a decrease of $20$35 million in the Under-recovered revenue decoupling regulatory asset, $17 million in the DC PLUG Charge regulatory asset, and $10 million in the Energy Efficiency and Demand Response Programs regulatory asset. Regulatory liabilities decreased $44 million primarily due to a decrease of $46 million in the Deferred Income Taxes regulatory liability.
ACE. Regulatory assets increased $179 million primarily due to an increase in the Electric Energy Costs regulatory asset as a result of the PPA termination. Regulatory liabilities decreased $16$19 million primarily due to a $9 million decrease of $13 million in the Deferred Income TaxesOver-Recovered Revenue Decoupling regulatory liability.
Capitalized Ratemaking Amounts Not Recognized
The following table presents authorized amounts capitalized for ratemaking purposes related to earnings on shareholders' investment that are not recognized for financial reporting purposes in the Registrants' Consolidated Balance Sheets. These amounts will be recognized as revenues in the related Consolidated Statements of Operations and Comprehensive Income in the periods they are billable to the Utility Registrants' customers. PECO had no related amounts as of March 31, 2023 and December 31, 2022.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Exelon | | ComEd(a) | | PECO | | BGE(b) | | PHI | | Pepco(c) | | DPL(c) | | ACE |
| June 30, 2022 | $ | 49 | | | $ | 4 | | | $ | — | | | $ | 32 | | | $ | 13 | | | $ | 11 | | | $ | 2 | | | $ | — | |
| | | | | | | | | | | | | | | |
| December 31, 2021 | 43 | | | 1 | | | — | | | 37 | | | 5 | | | 3 | | | 2 | | | — | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Exelon | | ComEd(a) | | BGE(b) | | PHI | | Pepco(c) | | DPL(c) | | ACE(b) |
| March 31, 2023 | | | $ | 53 | | | $ | 13 | | | $ | 26 | | | $ | 14 | | | $ | 11 | | | $ | 2 | | | $ | 1 | |
| | | | | | | | | | | | | | | |
| December 31, 2022 | | | 57 | | | 8 | | | 28 | | | 21 | | | 18 | | | 2 | | | 1 | |
__________
(a)Reflects ComEd's unrecognized equity returns earned for ratemaking purposes on its energy efficiency and electric distribution formula rate regulatory assets.
(b)BGE's and ACE's authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholder's investment on itstheir respective AMI programs.
(c)Pepco's and DPL's authorized amounts capitalized for ratemaking purposes relate to earnings on shareholder's investment on their respective AMI Programs and Energy Efficiency and Demand Response Programs, and for Pepco District of Columbia revenue decoupling program. The earnings on energy efficiency are on Pepco District of Columbia and DPL Delaware programs only.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 4 — Revenue from Contracts with Customers
4. Revenue from Contracts with Customers (All Registrants)
The Registrants recognize revenue from contracts with customers to depict the transfer of goods or services to customers at an amount that the entities expect to be entitled to in exchange for those goods or services. The primary sources of revenue include regulated electric and gas tariff sales, distribution, and transmission services.
See Note 4 — Revenue from Contracts with Customers of the 2021 Recast2022 Form 10-K for additional information regarding the primary sources of revenue for the Registrants.
Contract Liabilities
The Registrants record contract liabilities when consideration is received or due prior to the satisfaction of the performance obligations. The Registrants record contract liabilities in Other current liabilities and Other noncurrent deferred credits and other liabilities in their Consolidated Balance Sheets.
For PHI, Pepco, DPL, and ACE these contract liabilities primarily relate to upfront consideration received in the third quarter of 2020 for a collaborative arrangement with an unrelated owner and manager of communication infrastructure. The revenue attributable to this arrangement will be recognized as operating revenue over the 35 years under the collaborative arrangement.
The following table provides a rollforward of the contract liabilities reflected in Exelon's, PHI's, Pepco's, DPL's, and ACE's Consolidated Balance Sheets for the three and six months ended June 30, 2022March 31, 2023 and 2021.2022. As of June 30, 2022March 31, 2023 and December 31, 2021,2022, ComEd's, PECO's, and BGE's contract liabilities were immaterial.
| | | | | Exelon(a) | | PHI(a) | | Pepco(a) | | DPL | | ACE |
| Balance as of December 31, 2022 | | Balance as of December 31, 2022 | | $ | 101 | | | $ | 101 | | | $ | 81 | | | $ | 10 | | | $ | 10 | |
| Revenues recognized | | Revenues recognized | | (1) | | | (1) | | | (1) | | | — | | | — | |
| Balance as of March 31, 2023 | | Balance as of March 31, 2023 | | $ | 100 | | | $ | 100 | | | $ | 80 | | | $ | 10 | | | $ | 10 | |
| | | | | Exelon(a) | | PHI(a) | | Pepco(a) | | DPL | | ACE(a) | | Exelon(a) | | PHI(a) | | Pepco(a) | | DPL | | ACE |
| Balance as of December 31, 2021 | Balance as of December 31, 2021 | | $ | 109 | | | $ | 109 | | | $ | 87 | | | $ | 11 | | | $ | 11 | | Balance as of December 31, 2021 | | $ | 109 | | | $ | 109 | | | $ | 87 | | | $ | 11 | | | $ | 11 | |
| Revenues recognized | Revenues recognized | | (2) | | | (2) | | | (2) | | | — | | | — | | Revenues recognized | | (2) | | | (2) | | | (2) | | | — | | | — | |
| Balance as of March 31, 2022 | Balance as of March 31, 2022 | | 107 | | | 107 | | | 85 | | | 11 | | | 11 | | Balance as of March 31, 2022 | | $ | 107 | | | $ | 107 | | | $ | 85 | | | $ | 11 | | | $ | 11 | |
| Revenues recognized | | (2) | | | (2) | | | (1) | | | — | | | (1) | | |
| Balance as of June 30, 2022 | | $ | 105 | | | $ | 105 | | | $ | 84 | | | $ | 11 | | | $ | 10 | | |
| | | | Exelon(a) | | PHI(a) | | Pepco(a) | | DPL(a) | | ACE(a) | |
| Balance as of December 31, 2020 | | $ | 118 | | | $ | 118 | | | $ | 94 | | | $ | 12 | | | $ | 12 | | |
| Revenues recognized | | (2) | | | (2) | | | (2) | | | — | | | — | | |
| Balance as of March 31, 2021 | | 116 | | | 116 | | | 92 | | | 12 | | | 12 | | |
| Revenues recognized | | (3) | | | (3) | | | (1) | | | (1) | | | (1) | | |
| Balance as of June 30, 2021 | | $ | 113 | | | $ | 113 | | | $ | 91 | | | $ | 11 | | | $ | 11 | | |
|
(a)Revenues recognized in the three and six months ended June 30,March 31, 2023 and 2022, and 2021, were included in the contract liabilities at December 31, 20212022 and 2020,2021, respectively.
Transaction Price Allocated to Remaining Performance Obligations
The following table shows the amounts of future revenues expected to be recorded in each year for performance obligations that are unsatisfied or partially unsatisfied as of June 30, 2022.March 31, 2023. This disclosure only includes contracts for which the total consideration is fixed and determinable at contract inception. The average contract term varies by customer type and commodity but ranges from one month to several years.
This disclosure excludes the Utility Registrants' gas and electric tariff sales contracts and transmission revenue contracts as they generally have an original expected duration of one year or less and, therefore, do not contain any future, unsatisfied performance obligations to be included in this disclosure.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Year | Exelon | | PHI | | Pepco | | DPL | | ACE |
| 2023 | $ | 7 | | | $ | 7 | | | $ | 5 | | | $ | 1 | | | $ | 1 | |
| 2024 | 6 | | | 6 | | | 5 | | | — | | | 1 | |
| 2025 | 5 | | | 5 | | | 5 | | | — | | | — | |
| 2026 | 5 | | | 5 | | | 5 | | | — | | | — | |
| 2027 and thereafter | 77 | | | 77 | | | 60 | | | 9 | | | 8 | |
| Total | $ | 100 | | | $ | 100 | | | $ | 80 | | | $ | 10 | | | $ | 10 | |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 4 — Revenue from Contracts with Customers
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| 2022 | | 2023 | | 2024 | | 2025 | | 2026 and thereafter | | Total |
| Exelon | $ | 4 | | | $ | 8 | | | $ | 6 | | | $ | 5 | | | $ | 82 | | | $ | 105 | |
| PHI | 4 | | | 8 | | | 6 | | | 5 | | | 82 | | | 105 | |
| Pepco | 3 | | | 6 | | | 5 | | | 5 | | | 65 | | | 84 | |
| DPL | 1 | | | 1 | | | — | | | — | | | 9 | | | 11 | |
| ACE | — | | | 1 | | | 1 | | | — | | | 8 | | | 10 | |
Revenue Disaggregation
The Registrants disaggregate revenue recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. See Note 5 — Segment Information for the presentation of the Registrant'sRegistrants' revenue disaggregation.
5. Segment Information (All Registrants)
Operating segments for each of the Registrants are determined based on information used by the CODMs in deciding how to evaluate performance and allocate resources at each of the Registrants.
Exelon has 6six reportable segments, which include ComEd, PECO, BGE, and PHI's 3three reportable segments consisting of Pepco, DPL, and ACE. ComEd, PECO, BGE, Pepco, DPL, and ACE each represent a single reportable segment, and as such, no separate segment information is provided for these Registrants. Exelon, ComEd, PECO, BGE, Pepco, DPL, and ACE's CODMs evaluate the performance of and allocate resources to ComEd, PECO, BGE, Pepco, DPL, and ACEthe segments based on net income.
An analysis and reconciliation of the Registrants’ reportable segment information to the respective information in the consolidated financial statements for the three and six months ended June 30,March 31, 2023 and 2022 and 2021 is as follows:
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| ComEd | | PECO | | BGE | | PHI | | Other(a) | | Intersegment
Eliminations | | Exelon |
Operating revenues(b): | | | | | | | | | | | | | |
| 2023 | | | | | | | | | | | | | |
| Electric revenues | $ | 1,667 | | | $ | 795 | | | $ | 814 | | | $ | 1,436 | | | $ | — | | | $ | (5) | | | $ | 4,707 | |
| Natural gas revenues | — | | | 317 | | | 443 | | | 97 | | | — | | | (1) | | | 856 | |
| Shared service and other revenues | — | | | — | | | — | | | 3 | | | 437 | | | (440) | | | — | |
| Total operating revenues | $ | 1,667 | | | $ | 1,112 | | | $ | 1,257 | | | $ | 1,536 | | | $ | 437 | | | $ | (446) | | | $ | 5,563 | |
| 2022 | | | | | | | | | | | | | |
| Electric revenues | $ | 1,734 | | | $ | 741 | | | $ | 736 | | | $ | 1,318 | | | $ | — | | | $ | (7) | | | $ | 4,522 | |
| Natural gas revenues | — | | | 306 | | | 418 | | | 83 | | | — | | | (2) | | | 805 | |
| Shared service and other revenues | — | | | — | | | — | | | 3 | | | 576 | | | (579) | | | — | |
| Total operating revenues | $ | 1,734 | | | $ | 1,047 | | | $ | 1,154 | | | $ | 1,404 | | | $ | 576 | | | $ | (588) | | | $ | 5,327 | |
| | | | | | | | | | | | | |
Intersegment revenues(c): | | | | | | | | | | | | | |
| 2023 | $ | 3 | | | $ | 2 | | | $ | 3 | | | $ | 3 | | | $ | 434 | | | $ | (445) | | | $ | — | |
| 2022 | 6 | | | 1 | | | 7 | | | 3 | | | 576 | | | (587) | | | 6 | |
| Depreciation and amortization: | | | | | | | | | | | | | |
| 2023 | $ | 338 | | | $ | 98 | | | $ | 167 | | | $ | 241 | | | $ | 16 | | | $ | — | | | $ | 860 | |
| 2022 | 321 | | | 92 | | | 171 | | | 218 | | | 15 | | | — | | | 817 | |
| Operating expenses: | | | | | | | | | | | | | |
| 2023 | $ | 1,256 | | | $ | 902 | | | $ | 964 | | | $ | 1,297 | | | $ | 485 | | | $ | (447) | | | $ | 4,457 | |
| 2022 | 1,406 | | | 793 | | | 919 | | | 1,215 | | | 625 | | | (531) | | | 4,427 | |
| Interest expense, net: | | | | | | | | | | | | | |
| 2023 | $ | 117 | | | $ | 48 | | | $ | 44 | | | $ | 76 | | | $ | 127 | | | $ | — | | | $ | 412 | |
| 2022 | 100 | | | 41 | | | 35 | | | 69 | | | 93 | | | — | | | 338 | |
| Income (loss) from continuing operations before income taxes: | | | | | | | | | | | | | |
| 2023 | $ | 312 | | | $ | 170 | | | $ | 252 | | | $ | 189 | | | $ | (120) | | | $ | — | | | $ | 803 | |
| 2022 | 240 | | | 220 | | | 207 | | | 137 | | | (62) | | | (43) | | | 699 | |
| Income taxes: | | | | | | | | | | | | | |
| 2023 | $ | 71 | | | $ | 4 | | | $ | 52 | | | $ | 34 | | | $ | (27) | | | $ | — | | | $ | 134 | |
| 2022 | 52 | | | 14 | | | 9 | | | 7 | | | 146 | | | (10) | | | 218 | |
| Net income (loss) from continuing operations: | | | | | | | | | | | | | |
| 2023 | $ | 241 | | | $ | 166 | | | $ | 200 | | | $ | 155 | | | $ | (93) | | | $ | — | | | $ | 669 | |
| 2022 | 188 | | | 206 | | | 198 | | | 130 | | | (208) | | | (33) | | | 481 | |
| Capital expenditures: | | | | | | | | | | | | | |
| 2023 | $ | 617 | | | $ | 335 | | | $ | 350 | | | $ | 561 | | | $ | 18 | | | $ | — | | | $ | 1,881 | |
| 2022 | 617 | | | 344 | | | 303 | | | 409 | | | 22 | | | — | | | 1,695 | |
| Total assets: | | | | | | | | | | | | | |
| March 31, 2023 | $ | 40,720 | | | $ | 14,738 | | | $ | 13,411 | | | $ | 26,208 | | | $ | 6,042 | | | $ | (4,194) | | | $ | 96,925 | |
| December 31, 2022 | 39,661 | | | 14,502 | | | 13,350 | | | 26,082 | | | 6,014 | | | (4,260) | | | 95,349 | |
__________
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 5 — Segment Information
Three Months Ended June 30, 2022 and 2021
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| ComEd | | PECO | | BGE | | PHI | | Other(a) | | Intersegment
Eliminations | | Exelon |
Operating revenues(b): | | | | | | | | | | | | | |
| 2022 | | | | | | | | | | | | | |
| Electric revenues | $ | 1,425 | | | $ | 708 | | | $ | 629 | | | $ | 1,182 | | | $ | — | | | $ | (6) | | | $ | 3,938 | |
| Natural gas revenues | — | | | 108 | | | 157 | | | 37 | | | — | | | (1) | | | 301 | |
| Shared service and other revenues | — | | | — | | | — | | | 2 | | | 384 | | | (386) | | | — | |
| Total operating revenues | $ | 1,425 | | | $ | 816 | | | $ | 786 | | | $ | 1,221 | | | $ | 384 | | | $ | (393) | | | $ | 4,239 | |
| 2021 | | | | | | | | | | | | | |
| Electric revenues | $ | 1,517 | | | $ | 610 | | | $ | 558 | | | $ | 1,113 | | | $ | — | | | $ | (9) | | | $ | 3,789 | |
| Natural gas revenues | — | | | 83 | | | 124 | | | 24 | | | — | | | — | | | 231 | |
| Shared service and other revenues | — | | | — | | | — | | | 3 | | | 524 | | | (527) | | | — | |
| Total operating revenues | $ | 1,517 | | | $ | 693 | | | $ | 682 | | | $ | 1,140 | | | $ | 524 | | | $ | (536) | | | $ | 4,020 | |
| | | | | | | | | | | | | |
Intersegment revenues(c): | | | | | | | | | | | | | |
| 2022 | $ | 3 | | | $ | 1 | | | $ | 3 | | | $ | 2 | | | $ | 384 | | | $ | (393) | | | $ | — | |
| 2021 | 5 | | | 2 | | | 7 | | | 4 | | | 522 | | | (535) | | | 5 | |
| Depreciation and amortization: | | | | | | | | | | | | | |
| 2022 | $ | 328 | | | $ | 93 | | | $ | 152 | | | $ | 240 | | | $ | 16 | | | $ | 1 | | | $ | 830 | |
| 2021 | 296 | | | 87 | | | 141 | | | 194 | | | 18 | | | — | | | 736 | |
| Operating expenses: | | | | | | | | | | | | | |
| 2022 | $ | 1,039 | | | $ | 639 | | | $ | 717 | | | $ | 1,066 | | | $ | 460 | | | $ | (378) | | | $ | 3,543 | |
| 2021 | 1,196 | | | 552 | | | 620 | | | 955 | | | 495 | | | (374) | | | 3,444 | |
| Interest expense, net: | | | | | | | | | | | | | |
| 2022 | $ | 104 | | | $ | 43 | | | $ | 36 | | | $ | 73 | | | $ | 101 | | | $ | 1 | | | $ | 358 | |
| 2021 | 98 | | | 42 | | | 34 | | | 67 | | | 83 | | | — | | | 324 | |
| Income (loss) from continuing operations before income taxes: | | | | | | | | | | | | | |
| 2022 | $ | 293 | | | $ | 142 | | | $ | 38 | | | $ | 101 | | | $ | (62) | | | $ | (1) | | | $ | 511 | |
| 2021 | 238 | | | 106 | | | 37 | | | 138 | | | (46) | | | (144) | | | 329 | |
| Income Taxes: | | | | | | | | | | | | | |
| 2022 | $ | 66 | | | $ | 9 | | | $ | 1 | | | $ | 1 | | | $ | (31) | | | $ | — | | | $ | 46 | |
| 2021 | 46 | | | 2 | | | (8) | | | (3) | | | (27) | | | (7) | | | 3 | |
| Net income (loss) from continuing operations: | | | | | | | | | | | | | |
| 2022 | $ | 227 | | | $ | 133 | | | $ | 37 | | | $ | 100 | | | $ | (31) | | | $ | (1) | | | $ | 465 | |
| 2021 | 192 | | | 104 | | | 45 | | | 141 | | | (19) | | | (137) | | | 326 | |
| Capital Expenditures: | | | | | | | | | | | | | |
| 2022 | $ | 591 | | | $ | 314 | | | $ | 275 | | | $ | 367 | | | $ | 38 | | | $ | — | | | $ | 1,585 | |
| 2021 | 549 | | | 282 | | | 284 | | | 433 | | | 15 | | | — | | | 1,563 | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| | | | | | | | | | | | | |
__________(a)Other primarily includes Exelon’s corporate operations, shared service entities, and other financing and investment activities.
(b)Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 1415 — Supplemental Financial Information for additional information on total utility taxes.
(c)See Note 1516 — Related Party Transactions for additional information on intersegment revenues.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 5 — Segment Information
PHI:
| | | | Pepco | | DPL | | ACE | | Other(a) | | Intersegment
Eliminations | | PHI | | Pepco | | DPL | | ACE | | Other(a) | | Intersegment
Eliminations | | PHI |
Operating revenues(b): | Operating revenues(b): | | | | | | | | | | | | Operating revenues(b): | | | | | | | | | | | |
| 2023 | | 2023 | |
| Electric revenues | | Electric revenues | $ | 710 | | | $ | 377 | | | $ | 353 | | | $ | — | | | $ | (4) | | | $ | 1,436 | |
| Natural gas revenues | | Natural gas revenues | — | | | 97 | | | — | | | — | | | — | | | 97 | |
| Shared service and other revenues | | Shared service and other revenues | — | | | — | | | — | | | 102 | | | (99) | | | 3 | |
| Total operating revenues | | Total operating revenues | $ | 710 | | | $ | 474 | | | $ | 353 | | | $ | 102 | | | $ | (103) | | | $ | 1,536 | |
| 2022 | 2022 | | 2022 | | | | | | | | | | | |
| Electric revenues | Electric revenues | $ | 581 | | | $ | 295 | | | $ | 309 | | | $ | — | | | $ | (3) | | | $ | 1,182 | | Electric revenues | $ | 614 | | | $ | 348 | | | $ | 349 | | | $ | — | | | $ | 7 | | | $ | 1,318 | |
| Natural gas revenues | Natural gas revenues | — | | | 37 | | | — | | | — | | | — | | | 37 | | Natural gas revenues | — | | | 83 | | | — | | | — | | | — | | | 83 | |
| Shared service and other revenues | Shared service and other revenues | — | | | — | | | — | | | 98 | | | (96) | | | 2 | | Shared service and other revenues | — | | | — | | | — | | | 107 | | | (104) | | | 3 | |
| Total operating revenues | Total operating revenues | $ | 581 | | | $ | 332 | | | $ | 309 | | | $ | 98 | | | $ | (99) | | | $ | 1,221 | | Total operating revenues | $ | 614 | | | $ | 431 | | | $ | 349 | | | $ | 107 | | | $ | (97) | | | $ | 1,404 | |
| 2021 | | | | | | | | | | | | |
| Electric revenues | $ | 523 | | | $ | 274 | | | $ | 319 | | | $ | — | | | $ | (3) | | | $ | 1,113 | | |
| Natural gas revenues | — | | | 24 | | | — | | | — | | | — | | | 24 | | |
| Shared service and other revenues | — | | | — | | | — | | | 95 | | | (92) | | | 3 | | |
| Total operating revenues | $ | 523 | | | $ | 298 | | | $ | 319 | | | $ | 95 | | | $ | (95) | | | $ | 1,140 | | |
Intersegment revenues(c): | Intersegment revenues(c): | | | | | | | | | | | | Intersegment revenues(c): | | | | | | | | | | | |
| 2023 | | 2023 | $ | 1 | | | $ | 2 | | | $ | 1 | | | $ | 102 | | | $ | (103) | | | $ | 3 | |
| 2022 | 2022 | $ | 2 | | | $ | 2 | | | $ | 1 | | | $ | 98 | | | $ | (101) | | | $ | 2 | | 2022 | 1 | | | 1 | | | 1 | | | 97 | | | (97) | | | 3 | |
| 2021 | 1 | | | 2 | | | 1 | | | 95 | | | (95) | | | 4 | | |
| Depreciation and amortization: | Depreciation and amortization: | | Depreciation and amortization: | |
| 2023 | | 2023 | $ | 108 | | | $ | 60 | | | $ | 67 | | | $ | 6 | | | $ | — | | | $ | 241 | |
| 2022 | 2022 | $ | 105 | | | $ | 56 | | | $ | 72 | | | $ | 7 | | | $ | — | | | $ | 240 | | 2022 | 108 | | | 57 | | | 47 | | | 6 | | | — | | | 218 | |
| 2021 | 96 | | | 51 | | | 40 | | | 7 | | | — | | | 194 | | |
| Operating expenses: | Operating expenses: | | Operating expenses: | |
| 2023 | | 2023 | $ | 610 | | | $ | 388 | | | $ | 298 | | | $ | 104 | | | $ | (103) | | | $ | 1,297 | |
| 2022 | 2022 | $ | 487 | | | $ | 296 | | | $ | 283 | | | $ | 99 | | | $ | (99) | | | $ | 1,066 | | 2022 | 547 | | | 357 | | | 311 | | | 97 | | | (97) | | | 1,215 | |
| 2021 | 429 | | | 255 | | | 269 | | | 97 | | | (95) | | | 955 | | |
| Interest expense, net: | Interest expense, net: | | Interest expense, net: | |
| 2023 | | 2023 | $ | 39 | | | $ | 17 | | | $ | 16 | | | $ | 4 | | | $ | — | | | $ | 76 | |
| 2022 | 2022 | $ | 38 | | | $ | 17 | | | $ | 17 | | | $ | 1 | | | $ | — | | | $ | 73 | | 2022 | 36 | | | 16 | | | 14 | | | 3 | | | — | | | 69 | |
| 2021 | 35 | | | 16 | | | 14 | | | 2 | | | — | | | 67 | | |
| Income (loss) before income taxes: | Income (loss) before income taxes: | | Income (loss) before income taxes: | |
| 2023 | | 2023 | $ | 77 | | | $ | 72 | | | $ | 44 | | | $ | (4) | | | $ | — | | | $ | 189 | |
| 2022 | 2022 | $ | 69 | | | $ | 23 | | | $ | 11 | | | $ | (2) | | | $ | — | | | $ | 101 | | 2022 | 44 | | | 60 | | | 27 | | | 6 | | | — | | | 137 | |
| 2021 | 72 | | | 31 | | | 36 | | | (1) | | | — | | | 138 | | |
| Income Taxes: | | |
| Income taxes: | | Income taxes: | |
| 2023 | | 2023 | $ | 12 | | | $ | 12 | | | $ | 11 | | | $ | (1) | | | $ | — | | | $ | 34 | |
| 2022 | 2022 | $ | (1) | | | $ | 2 | | | $ | — | | | $ | — | | | $ | — | | | $ | 1 | | 2022 | (2) | | | 4 | | | 1 | | | 4 | | | — | | | 7 | |
| 2021 | (3) | | | 1 | | | (1) | | | — | | | — | | | (3) | | |
| Net income (loss): | Net income (loss): | | Net income (loss): | |
| 2023 | | 2023 | $ | 65 | | | $ | 60 | | | $ | 33 | | | $ | (3) | | | $ | — | | | $ | 155 | |
| 2022 | 2022 | $ | 70 | | | $ | 21 | | | $ | 11 | | | $ | (2) | | | $ | — | | | $ | 100 | | 2022 | 46 | | | 56 | | | 26 | | | 2 | | | — | | | 130 | |
| 2021 | 75 | | | 30 | | | 37 | | | (1) | | | — | | | 141 | | |
| Capital Expenditures: | | |
| Capital expenditures: | | Capital expenditures: | |
| 2023 | | 2023 | $ | 264 | | | $ | 134 | | | $ | 161 | | | $ | 2 | | | $ | — | | | $ | 561 | |
| 2022 | 2022 | $ | 184 | | | $ | 91 | | | $ | 92 | | | $ | — | | | $ | — | | | $ | 367 | | 2022 | 218 | | | 103 | | | 87 | | | 1 | | | — | | | 409 | |
| 2021 | 219 | | | 99 | | | 116 | | | (1) | | | — | | | 433 | | |
| | Total assets: | | Total assets: | |
| March 31, 2023 | | March 31, 2023 | $ | 10,795 | | | $ | 5,804 | | | $ | 5,013 | | | $ | 4,638 | | | $ | (42) | | | $ | 26,208 | |
| December 31, 2022 | | December 31, 2022 | 10,657 | | | 5,802 | | | 4,979 | | | 4,677 | | | (33) | | | 26,082 | |
__________
(a)Other primarily includes PHI’s corporate operations, shared service entities, and other financing and investment activities.
(b)Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 1415 — Supplemental Financial Information for additional information on total utility taxes.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 5 — Segment Information
(c)Includes intersegment revenues with ComEd, BGE, and PECO, which are eliminated at Exelon.
The following tables disaggregate the Registrants' revenues recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of electric sales and natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon’s disaggregated revenues are consistent with the Utility Registrants, but exclude any intercompany revenues.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| Three Months Ended March 31, 2023 |
| Revenues from contracts with customers | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Electric revenues | | | | | | | | | | | | | |
| Residential | $ | 836 | | | $ | 519 | | | $ | 434 | | | $ | 639 | | | $ | 283 | | | $ | 210 | | | $ | 146 | |
| Small commercial & industrial | 361 | | | 135 | | | 92 | | | 160 | | | 39 | | | 62 | | | 59 | |
| Large commercial & industrial | 84 | | | 65 | | | 149 | | | 378 | | | 282 | | | 33 | | | 63 | |
| Public authorities & electric railroads | 10 | | | 8 | | | 7 | | | 17 | | | 8 | | | 4 | | | 5 | |
Other(a) | 217 | | | 68 | | | 96 | | | 176 | | | 56 | | | 58 | | | 63 | |
Total electric revenues(b) | $ | 1,508 | | | $ | 795 | | | $ | 778 | | | $ | 1,370 | | | $ | 668 | | | $ | 367 | | | $ | 336 | |
| Natural gas revenues | | | | | | | | | | | | | |
| Residential | $ | — | | | $ | 223 | | | $ | 278 | | | $ | 60 | | | $ | — | | | $ | 60 | | | $ | — | |
| Small commercial & industrial | — | | | 75 | | | 41 | | | 26 | | | — | | | 26 | | | — | |
| Large commercial & industrial | — | | | 1 | | | 70 | | | 1 | | | — | | | 1 | | | — | |
| Transportation | — | | | 8 | | | — | | | 4 | | | — | | | 4 | | | — | |
Other(c) | — | | | 9 | | | 19 | | | 6 | | | — | | | 6 | | | — | |
Total natural gas revenues(d) | $ | — | | | $ | 316 | | | $ | 408 | | | $ | 97 | | | $ | — | | | $ | 97 | | | $ | — | |
| Total revenues from contracts with customers | $ | 1,508 | | | $ | 1,111 | | | $ | 1,186 | | | $ | 1,467 | | | $ | 668 | | | $ | 464 | | | $ | 336 | |
| Other revenues | | | | | | | | | | | | | |
| Revenues from alternative revenue programs | $ | 153 | | | $ | (4) | | | $ | 65 | | | $ | 65 | | | $ | 39 | | | $ | 9 | | | $ | 17 | |
Other electric revenues(e) | 6 | | | 4 | | | 4 | | | 4 | | | 3 | | | 1 | | | — | |
Other natural gas revenues(e) | — | | | 1 | | | 2 | | | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | |
| Total other revenues | $ | 159 | | | $ | 1 | | | $ | 71 | | | $ | 69 | | | $ | 42 | | | $ | 10 | | | $ | 17 | |
| Total revenues for reportable segments | $ | 1,667 | | | $ | 1,112 | | | $ | 1,257 | | | $ | 1,536 | | | $ | 710 | | | $ | 474 | | | $ | 353 | |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 5 — Segment Information
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | |
| Three Months Ended June 30, 2022 |
| Revenues from contracts with customers | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Electric revenues | | | | | | | | | | | | | |
| Residential | $ | 819 | | | $ | 431 | | | $ | 334 | | | $ | 548 | | | $ | 234 | | | $ | 155 | | | $ | 159 | |
| Small commercial & industrial | 312 | | | 126 | | | 70 | | | 140 | | | 35 | | | 51 | | | 54 | |
| Large commercial & industrial | 11 | | | 72 | | | 129 | | | 332 | | | 250 | | | 30 | | | 52 | |
| Public authorities & electric railroads | 5 | | | 7 | | | 7 | | | 15 | | | 8 | | | 3 | | | 4 | |
Other(a) | 234 | | | 68 | | | 99 | | | 164 | | | 54 | | | 57 | | | 55 | |
Total electric revenues(b) | $ | 1,381 | | | $ | 704 | | | $ | 639 | | | $ | 1,199 | | | $ | 581 | | | $ | 296 | | | $ | 324 | |
| Natural gas revenues | | | | | | | | | | | | | |
| Residential | $ | — | | | $ | 71 | | | $ | 96 | | | $ | 17 | | | $ | — | | | $ | 17 | | | $ | — | |
| Small commercial & industrial | — | | | 29 | | | 18 | | | 8 | | | — | | | 8 | | | — | |
| Large commercial & industrial | — | | | — | | | 35 | | | 3 | | | — | | | 3 | | | — | |
| Transportation | — | | | 6 | | | — | | | 3 | | | — | | | 3 | | | — | |
Other(c) | — | | | 2 | | | 12 | | | 6 | | | — | | | 6 | | | — | |
Total Natural gas revenues(d) | $ | — | | | $ | 108 | | | $ | 161 | | | $ | 37 | | | $ | — | | | $ | 37 | | | $ | — | |
| Total revenues from contracts with customers | $ | 1,381 | | | $ | 812 | | | $ | 800 | | | $ | 1,236 | | | $ | 581 | | | $ | 333 | | | $ | 324 | |
| | | | | | | | | | | | | |
| Other revenues | | | | | | | | | | | | | |
| Revenues from alternative revenue programs | $ | 35 | | | $ | — | | | $ | (20) | | | $ | (17) | | | $ | (1) | | | $ | (2) | | | $ | (15) | |
Other electric revenues(e) | 9 | | | 4 | | | 4 | | | 2 | | | 1 | | | 1 | | | — | |
Other natural gas revenues(e) | — | | | — | | | 2 | | | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | |
| Total other revenues | $ | 44 | | | $ | 4 | | | $ | (14) | | | $ | (15) | | | $ | — | | | $ | (1) | | | $ | (15) | |
| Total revenues for reportable segments | $ | 1,425 | | | $ | 816 | | | $ | 786 | | | $ | 1,221 | | | $ | 581 | | | $ | 332 | | | $ | 309 | |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 5 — Segment Information
| | | | Three Months Ended June 30, 2021 | | Three Months Ended March 31, 2022 |
| Revenues from contracts with customers | Revenues from contracts with customers | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE | Revenues from contracts with customers | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Electric revenues | Electric revenues | | | | | | | | | | | | | | Electric revenues | | | | | | | | | | | | | |
| Residential | Residential | $ | 759 | | | $ | 383 | | | $ | 299 | | | $ | 537 | | | $ | 223 | | | $ | 147 | | | $ | 167 | | Residential | $ | 857 | | | $ | 487 | | | $ | 417 | | | $ | 652 | | | $ | 275 | | | $ | 207 | | | $ | 170 | |
| Small commercial & industrial | Small commercial & industrial | 377 | | | 99 | | | 60 | | | 124 | | | 32 | | | 46 | | | 46 | | Small commercial & industrial | 423 | | | 111 | | | 81 | | | 141 | | | 38 | | | 56 | | | 47 | |
| Large commercial & industrial | Large commercial & industrial | 138 | | | 59 | | | 108 | | | 257 | | | 188 | | | 22 | | | 47 | | Large commercial & industrial | 153 | | | 64 | | | 131 | | | 323 | | | 253 | | | 26 | | | 44 | |
| Public authorities & electric railroads | Public authorities & electric railroads | 11 | | | 8 | | | 7 | | | 17 | | | 10 | | | 3 | | | 4 | | Public authorities & electric railroads | 14 | | | 8 | | | 7 | | | 16 | | | 8 | | | 4 | | | 4 | |
Other(a) | Other(a) | 214 | | | 54 | | | 87 | | | 139 | | | 50 | | | 46 | | | 43 | | Other(a) | 239 | | | 62 | | | 97 | | | 193 | | | 46 | | | 56 | | | 81 | |
Total electric revenues(b) | Total electric revenues(b) | $ | 1,499 | | | $ | 603 | | | $ | 561 | | | $ | 1,074 | | | $ | 503 | | | $ | 264 | | | $ | 307 | | Total electric revenues(b) | $ | 1,686 | | | $ | 732 | | | $ | 733 | | | $ | 1,325 | | | $ | 620 | | | $ | 349 | | | $ | 346 | |
| Natural gas revenues | Natural gas revenues | | Natural gas revenues | |
| Residential | Residential | $ | — | | | $ | 55 | | | $ | 81 | | | $ | 12 | | | $ | — | | | $ | 12 | | | $ | — | | Residential | $ | — | | | $ | 218 | | | $ | 282 | | | $ | 51 | | | $ | — | | | $ | 51 | | | $ | — | |
| Small commercial & industrial | Small commercial & industrial | — | | | 22 | | | 13 | | | 6 | | | — | | | 6 | | | — | | Small commercial & industrial | — | | | 76 | | | 45 | | | 21 | | | — | | | 21 | | | — | |
| Large commercial & industrial | Large commercial & industrial | — | | | — | | | 27 | | | 1 | | | — | | | 1 | | | — | | Large commercial & industrial | — | | | — | | | 65 | | | 3 | | | — | | | 3 | | | — | |
| Transportation | Transportation | — | | | 5 | | | — | | | 3 | | | — | | | 3 | | | — | | Transportation | — | | | 8 | | | — | | | 4 | | | — | | | 4 | | | — | |
Other(c) | Other(c) | — | | | 1 | | | 6 | | | 2 | | | — | | | 2 | | | — | | Other(c) | — | | | 3 | | | 35 | | | 4 | | | — | | | 4 | | | — | |
Total natural gas revenues(d) | Total natural gas revenues(d) | $ | — | | | $ | 83 | | | $ | 127 | | | $ | 24 | | | $ | — | | | $ | 24 | | | $ | — | | Total natural gas revenues(d) | $ | — | | | $ | 305 | | | $ | 427 | | | $ | 83 | | | $ | — | | | $ | 83 | | | $ | — | |
| Total revenues from contracts with customers | Total revenues from contracts with customers | $ | 1,499 | | | $ | 686 | | | $ | 688 | | | $ | 1,098 | | | $ | 503 | | | $ | 288 | | | $ | 307 | | Total revenues from contracts with customers | $ | 1,686 | | | $ | 1,037 | | | $ | 1,160 | | | $ | 1,408 | | | $ | 620 | | | $ | 432 | | | $ | 346 | |
| | Other revenues | Other revenues | | Other revenues | |
| Revenues from alternative revenue programs | Revenues from alternative revenue programs | $ | 9 | | | $ | 7 | | | $ | (10) | | | $ | 41 | | | $ | 19 | | | $ | 10 | | | $ | 12 | | Revenues from alternative revenue programs | $ | 40 | | | $ | 6 | | | $ | (12) | | | $ | (5) | | | $ | (7) | | | $ | (1) | | | $ | 3 | |
Other electric revenues(e) | Other electric revenues(e) | 9 | | | — | | | 3 | | | 1 | | | 1 | | | — | | | — | | Other electric revenues(e) | 8 | | | 3 | | | 4 | | | 1 | | | 1 | | | — | | | — | |
Other natural gas revenues(e) | Other natural gas revenues(e) | — | | | — | | | 1 | | | — | | | — | | | — | | | — | | Other natural gas revenues(e) | — | | | 1 | | | 2 | | | — | | | — | | | — | | | — | |
| | Total other revenues | Total other revenues | $ | 18 | | | $ | 7 | | | $ | (6) | | | $ | 42 | | | $ | 20 | | | $ | 10 | | | $ | 12 | | Total other revenues | $ | 48 | | | $ | 10 | | | $ | (6) | | | $ | (4) | | | $ | (6) | | | $ | (1) | | | $ | 3 | |
| Total revenues for reportable segments | Total revenues for reportable segments | $ | 1,517 | | | $ | 693 | | | $ | 682 | | | $ | 1,140 | | | $ | 523 | | | $ | 298 | | | $ | 319 | | Total revenues for reportable segments | $ | 1,734 | | | $ | 1,047 | | | $ | 1,154 | | | $ | 1,404 | | | $ | 614 | | | $ | 431 | | | $ | 349 | |
__________
(a)Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue.
(b)Includes operating revenues from affiliates in 20222023 and 20212022 respectively of:
•$3 million, $5$6 million at ComEd
•$1 million, $1 million at PECO
•$2 million, $4$2 million at BGE
•$23 million, $4$3 million at PHI
•$21 million, $1 million at Pepco
•$2 million, $2 million at DPL
•$1 million, $1 million at ACE
(c)Includes revenues from off-system natural gas sales.
(d)Includes operating revenues from affiliates in 20222023 and 20212022 respectively of:
•less than $1$1 million, less than a $1 million at PECO
•$1 million, $3$6 million at BGE
(e)Includes late payment charge revenues.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 5 — Segment Information
Six Months Ended June 30, 2022 and 2021
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| ComEd | | PECO | | BGE | | PHI | | Other(a) | | Intersegment
Eliminations | | Exelon |
Operating revenues(b): | | | | | | | | | | | | | |
| 2022 | | | | | | | | | | | | | |
| Electric revenues | $ | 3,158 | | | $ | 1,449 | | | $ | 1,366 | | | $ | 2,501 | | | $ | — | | | $ | (14) | | | $ | 8,460 | |
| Natural gas revenues | — | | | 414 | | | 574 | | | 120 | | | — | | | (2) | | | 1,106 | |
| Shared service and other revenues | — | | | — | | | — | | | 5 | | | 961 | | | (966) | | | — | |
| Total operating revenues | $ | 3,158 | | | $ | 1,863 | | | $ | 1,940 | | | $ | 2,626 | | | $ | 961 | | | $ | (982) | | | $ | 9,566 | |
| 2021 | | | | | | | | | | | | | |
| Electric revenues | $ | 3,052 | | | $ | 1,271 | | | $ | 1,190 | | | $ | 2,283 | | | $ | — | | | $ | (16) | | | $ | 7,780 | |
| Natural gas revenues | — | | | 311 | | | 466 | | | 95 | | | — | | | — | | | 872 | |
| Shared service and other revenues | — | | | — | | | — | | | 6 | | | 1,013 | | | (1,019) | | | — | |
| Total operating revenues | $ | 3,052 | | | $ | 1,582 | | | $ | 1,656 | | | $ | 2,384 | | | $ | 1,013 | | | $ | (1,035) | | | $ | 8,652 | |
| | | | | | | | | | | | | |
Intersegment revenues(c): | | | | | | | | | | | | | |
| 2022 | $ | 8 | | | $ | 2 | | | $ | 10 | | | $ | 6 | | | $ | 961 | | | $ | (981) | | | $ | 6 | |
| 2021 | 11 | | | 4 | | | 13 | | | 7 | | | 1,010 | | | (1,033) | | | 12 | |
| Depreciation and amortization: | | | | | | | | | | | | | |
| 2022 | $ | 649 | | | $ | 185 | | | $ | 322 | | | $ | 459 | | | $ | 32 | | | $ | — | | | $ | 1,647 | |
| 2021 | 589 | | | 173 | | | 293 | | | 404 | | | 35 | | | — | | | 1,494 | |
| Operating expenses: | | | | | | | | | | | | | |
| 2022 | $ | 2,444 | | | $ | 1,432 | | | $ | 1,636 | | | $ | 2,282 | | | $ | 1,086 | | | $ | (909) | | | $ | 7,971 | |
| 2021 | 2,406 | | | 1,231 | | | 1,372 | | | 2,013 | | | 943 | | | (713) | | | 7,252 | |
| Interest expense, net: | | | | | | | | | | | | | |
| 2022 | $ | 204 | | | $ | 84 | | | $ | 71 | | | $ | 143 | | | $ | 195 | | | $ | — | | | $ | 697 | |
| 2021 | 193 | | | 80 | | | 67 | | | 134 | | | 169 | | | — | | | 643 | |
| Income (loss) from continuing operations before income taxes: | | | | | | | | | | | | | |
| 2022 | $ | 534 | | | $ | 363 | | | $ | 244 | | | $ | 238 | | | $ | (125) | | | $ | (45) | | | $ | 1,209 | |
| 2021 | 475 | | | 283 | | | 233 | | | 273 | | | (80) | | | (292) | | | 892 | |
| Income Taxes: | | | | | | | | | | | | | |
| 2022 | $ | 119 | | | $ | 24 | | | $ | 10 | | | $ | 8 | | | $ | 114 | | | $ | (12) | | | $ | 263 | |
| 2021 | 85 | | | 12 | | | (21) | | | 5 | | | (19) | | | (20) | | | 42 | |
| Net income (loss) from continuing operations: | | | | | | | | | | | | | |
| 2022 | $ | 415 | | | $ | 339 | | | $ | 234 | | | $ | 230 | | | $ | (239) | | | $ | (33) | | | $ | 946 | |
| 2021 | 390 | | | 271 | | | 254 | | | 269 | | | (61) | | | (272) | | | 851 | |
| Capital Expenditures: | | | | | | | | | | | | | |
| 2022 | $ | 1,208 | | | $ | 658 | | | $ | 578 | | | $ | 776 | | | $ | 60 | | | $ | — | | | $ | 3,280 | |
| 2021 | 1,162 | | | 577 | | | 620 | | | 889 | | | 61 | | | — | | | 3,309 | |
| Total assets: | | | | | | | | | | | | | |
| June 30, 2022 | $ | 37,194 | | | $ | 14,216 | | | $ | 13,093 | | | $ | 25,592 | | | $ | 6,345 | | | $ | (4,145) | | | $ | 92,295 | |
| December 31, 2021 | 36,470 | | | 13,824 | | | 12,324 | | | 24,744 | | | 7,626 | | | (8,319) | | | 86,669 | |
__________
(a)Other primarily includes Exelon’s corporate operations, shared service entities, and other financing and investment activities.
(b)Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 14 — Supplemental Financial Information for additional information on total utility taxes.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 5 — Segment Information
(c)See Note 15 — Related Party Transactions for additional information on intersegment revenues.
PHI:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Pepco | | DPL | | ACE | | Other(a) | | Intersegment
Eliminations | | PHI |
Operating revenues(b): | | | | | | | | | | | |
| 2022 | | | | | | | | | | | |
| Electric revenues | $ | 1,195 | | | $ | 643 | | | $ | 658 | | | $ | — | | | $ | 5 | | | $ | 2,501 | |
| Natural gas revenues | — | | | 120 | | | — | | | — | | | — | | | 120 | |
| Shared service and other revenues | — | | | — | | | — | | | 205 | | | (200) | | | 5 | |
| Total operating revenues | $ | 1,195 | | | $ | 763 | | | $ | 658 | | | $ | 205 | | | $ | (195) | | | $ | 2,626 | |
| 2021 | | | | | | | | | | | |
| Electric revenues | $ | 1,076 | | | $ | 585 | | | $ | 629 | | | $ | — | | | $ | (7) | | | $ | 2,283 | |
| Natural gas revenues | — | | | 95 | | | — | | | — | | | — | | | 95 | |
| Shared service and other revenues | — | | | — | | | — | | | 189 | | | (183) | | | 6 | |
| Total operating revenues | $ | 1,076 | | | $ | 680 | | | $ | 629 | | | $ | 189 | | | $ | (190) | | | $ | 2,384 | |
Intersegment revenues(c): | | | | | | | | | | | |
| 2022 | $ | 2 | | | $ | 3 | | | $ | 2 | | | $ | 195 | | | $ | (196) | | | $ | 6 | |
| 2021 | 3 | | | 4 | | | 1 | | | 189 | | | (190) | | | 7 | |
| Depreciation and amortization: | | | | | | | | | | | |
| 2022 | $ | 213 | | | $ | 113 | | | $ | 118 | | | $ | 15 | | | $ | — | | | $ | 459 | |
| 2021 | 199 | | | 104 | | | 87 | | | 14 | | | — | | | 404 | |
| Operating expenses: | | | | | | | | | | | |
| 2022 | $ | 1,034 | | | $ | 653 | | | $ | 593 | | | $ | 197 | | | $ | (195) | | | $ | 2,282 | |
| 2021 | 895 | | | 564 | | | 552 | | | 192 | | | (190) | | | 2,013 | |
| Interest expense, net: | | | | | | | | | | | |
| 2022 | $ | 74 | | | $ | 33 | | | $ | 32 | | | $ | 5 | | | $ | (1) | | | $ | 143 | |
| 2021 | 69 | | | 30 | | | 29 | | | 6 | | | — | | | 134 | |
| Income (loss) before income taxes: | | | | | | | | | | | |
| 2022 | $ | 113 | | | $ | 83 | | | $ | 38 | | | $ | 4 | | | $ | — | | | $ | 238 | |
| 2021 | 137 | | | 92 | | | 50 | | | (6) | | | — | | | 273 | |
| Income Taxes: | | | | | | | | | | | |
| 2022 | $ | (3) | | | $ | 6 | | | $ | 1 | | | $ | 4 | | | $ | — | | | $ | 8 | |
| 2021 | 3 | | | 6 | | | (1) | | | (3) | | | — | | | 5 | |
| Net income (loss): | | | | | | | | | | | |
| 2022 | $ | 116 | | | $ | 77 | | | $ | 37 | | | $ | — | | | $ | — | | | $ | 230 | |
| 2021 | 134 | | | 86 | | | 51 | | | (2) | | | — | | | 269 | |
| Capital Expenditures: | | | | | | | | | | | |
| 2022 | $ | 402 | | | $ | 194 | | | $ | 179 | | | $ | 1 | | | $ | — | | | $ | 776 | |
| 2021 | 439 | | | 211 | | | 239 | | | — | | | — | | | 889 | |
| Total assets: | | | | | | | | | | | |
| June 30, 2022 | $ | 10,226 | | | $ | 5,742 | | | $ | 5,052 | | | $ | 4,775 | | | $ | (203) | | | $ | 25,592 | |
| December 31, 2021 | 9,903 | | | 5,412 | | | 4,556 | | | 4,933 | | | (60) | | | 24,744 | |
__________
(a)Other primarily includes PHI’s corporate operations, shared service entities, and other financing and investment activities.
(b)Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 14 — Supplemental Financial Information for additional information on total utility taxes.
(c)Includes intersegment revenues with ComEd, BGE, and PECO, which are eliminated at Exelon.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 5 — Segment Information
The following tables disaggregate the Registrants' revenues recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of electric sales and natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon’s disaggregated revenues are consistent with the Utility Registrants, but exclude any intercompany revenues.
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| Six Months Ended June 30, 2022 |
| Revenues from contracts with customers | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Electric revenues | | | | | | | | | | | | | |
| Residential | $ | 1,675 | | | $ | 918 | | | $ | 752 | | | $ | 1,200 | | | $ | 509 | | | $ | 362 | | | $ | 329 | |
| Small commercial & industrial | 736 | | | 237 | | | 151 | | | 281 | | | 73 | | | 107 | | | 101 | |
| Large commercial & industrial | 165 | | | 136 | | | 260 | | | 655 | | | 503 | | | 56 | | | 96 | |
| Public authorities & electric railroads | 20 | | | 15 | | | 14 | | | 31 | | | 16 | | | 7 | | | 8 | |
Other(a) | 472 | | | 130 | | | 196 | | | 359 | | | 100 | | | 113 | | | 136 | |
Total electric revenues(b) | $ | 3,068 | | | $ | 1,436 | | | $ | 1,373 | | | $ | 2,526 | | | $ | 1,201 | | | $ | 645 | | | $ | 670 | |
| Natural gas revenues | | | | | | | | | | | | | |
| Residential | $ | — | | | $ | 289 | | | $ | 378 | | | $ | 68 | | | $ | — | | | $ | 68 | | | $ | — | |
| Small commercial & industrial | — | | | 105 | | | 63 | | | 29 | | | — | | | 29 | | | — | |
| Large commercial & industrial | — | | | — | | | 100 | | | 6 | | | — | | | 6 | | | — | |
| Transportation | — | | | 14 | | | — | | | 7 | | | — | | | 7 | | | — | |
Other(c) | — | | | 5 | | | 47 | | | 10 | | | — | | | 10 | | | — | |
Total natural gas revenues(d) | $ | — | | | $ | 413 | | | $ | 588 | | | $ | 120 | | | $ | — | | | $ | 120 | | | $ | — | |
| Total revenues from contracts with customers | $ | 3,068 | | | $ | 1,849 | | | $ | 1,961 | | | $ | 2,646 | | | $ | 1,201 | | | $ | 765 | | | $ | 670 | |
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| Other revenues | | | | | | | | | | | | | |
| Revenues from alternative revenue programs | $ | 75 | | | $ | 6 | | | $ | (32) | | | $ | (22) | | | $ | (7) | | | $ | (3) | | | $ | (12) | |
Other electric revenues(e) | 15 | | | 7 | | | 8 | | | 2 | | | 1 | | | 1 | | | — | |
Other natural gas revenues(e) | — | | | 1 | | | 3 | | | — | | | — | | | — | | | — | |
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| Total other revenues | $ | 90 | | | $ | 14 | | | $ | (21) | | | $ | (20) | | | $ | (6) | | | $ | (2) | | | $ | (12) | |
| Total revenues for reportable segments | $ | 3,158 | | | $ | 1,863 | | | $ | 1,940 | | | $ | 2,626 | | | $ | 1,195 | | | $ | 763 | | | $ | 658 | |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 5 — Segment Information
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| Six Months Ended June 30, 2021 |
| Revenues from contracts with customers | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Electric revenues | | | | | | | | | | | | | |
| Residential | $ | 1,502 | | | $ | 816 | | | $ | 662 | | | $ | 1,142 | | | $ | 476 | | | $ | 337 | | | $ | 329 | |
| Small commercial & industrial | 744 | | | 199 | | | 129 | | | 242 | | | 65 | | | 92 | | | 85 | |
| Large commercial & industrial | 271 | | | 116 | | | 213 | | | 505 | | | 372 | | | 43 | | | 90 | |
| Public authorities & electric railroads | 22 | | | 17 | | | 13 | | | 30 | | | 16 | | | 7 | | | 7 | |
Other(a) | 433 | | | 106 | | | 165 | | | 283 | | | 101 | | | 87 | | | 95 | |
Total electric revenues(b) | $ | 2,972 | | | $ | 1,254 | | | $ | 1,182 | | | $ | 2,202 | | | $ | 1,030 | | | $ | 566 | | | $ | 606 | |
| Natural gas revenues | | | | | | | | | | | | | |
| Residential | $ | — | | | $ | 215 | | | $ | 297 | | | $ | 57 | | | $ | — | | | $ | 57 | | | $ | — | |
| Small commercial & industrial | — | | | 81 | | | 48 | | | 24 | | | — | | | 24 | | | — | |
| Large commercial & industrial | — | | | — | | | 81 | | | 3 | | | — | | | 3 | | | — | |
| Transportation | — | | | 12 | | | — | | | 8 | | | — | | | 8 | | | — | |
Other(c) | — | | | 3 | | | 36 | | | 2 | | | — | | | 3 | | | — | |
Total natural gas revenues(d) | $ | — | | | $ | 311 | | | $ | 462 | | | $ | 94 | | | $ | — | | | $ | 95 | | | $ | — | |
| Total revenues from contracts with customers | $ | 2,972 | | | $ | 1,565 | | | $ | 1,644 | | | $ | 2,296 | | | $ | 1,030 | | | $ | 661 | | | $ | 606 | |
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| Other revenues | | | | | | | | | | | | | |
| Revenues from alternative revenue programs | $ | 64 | | | $ | 17 | | | $ | 8 | | | $ | 88 | | | $ | 46 | | | $ | 19 | | | $ | 23 | |
Other electric revenues(e) | 16 | | | — | | | 3 | | | — | | | — | | | — | | | — | |
Other natural gas revenues(e) | — | | | — | | | 1 | | | — | | | — | | | — | | | — | |
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| Total other revenues | $ | 80 | | | $ | 17 | | | $ | 12 | | | $ | 88 | | | $ | 46 | | | $ | 19 | | | $ | 23 | |
| Total revenues for reportable segments | $ | 3,052 | | | $ | 1,582 | | | $ | 1,656 | | | $ | 2,384 | | | $ | 1,076 | | | $ | 680 | | | $ | 629 | |
__________
(a)Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue.
(b)Includes operating revenues from affiliates in 2022 and 2021 respectively of:
•$8 million, $11 million at ComEd
•$2 million, $3 million at PECO
•$3 million, $5 million at BGE
•$6 million, $7 million at PHI
•$2 million, $3 million at Pepco
•$3 million, $4 million at DPL
•$2 million, $1 million at ACE
(c)Includes revenues from off-system natural gas sales.
(d)Includes operating revenues from affiliates in 2022 and 2021 respectively of:
•less than $1 million, $1 million at PECO
•$7 million, $7 million at BGE
(e)Includes late payment charge revenues.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 6 — Accounts Receivable
6. Accounts Receivable (All Registrants)
Allowance for Credit Losses on Accounts Receivable
The following tables present the rollforward of Allowance for Credit Losses on Customer Accounts Receivable.
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| Three Months Ended June 30, 2022 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of March 31, 2022 | $ | 389 | | | $ | 92 | | | $ | 125 | | | $ | 59 | | | $ | 113 | | | $ | 40 | | | $ | 24 | | | $ | 49 | |
| Plus: Current period (benefit) provision for expected credit losses | (9) | | | (5) | | | (10) | | | 2 | | | 4 | | | 5 | | | — | | | (1) | |
Less: Write-offs, net of recoveries(a) | 26 | | | 6 | | | 8 | | | 4 | | | 8 | | | 3 | | | 2 | | | 3 | |
| Balance as of June 30, 2022 | $ | 354 | | | $ | 81 | | | $ | 107 | | | $ | 57 | | | $ | 109 | | | $ | 42 | | | $ | 22 | | | $ | 45 | |
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| Three Months Ended June 30, 2021 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of March 31, 2021 | $ | 377 | | | $ | 103 | | | $ | 130 | | | $ | 43 | | | $ | 101 | | | $ | 41 | | | $ | 25 | | | $ | 35 | |
| Plus: Current period (benefit) provision for expected credit losses | (42) | | | (9) | | | (14) | | | (14) | | | (5) | | | (1) | | | (5) | | | 1 | |
Less: Write-offs, net of recoveries(a) | 15 | | | 5 | | | 5 | | | 2 | | | 3 | | | 2 | | | 1 | | | — | |
| Balance as of June 30, 2021 | $ | 320 | | | $ | 89 | | | $ | 111 | | | $ | 27 | | | $ | 93 | | | $ | 38 | | | $ | 19 | | | $ | 36 | |
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| Six Months Ended June 30, 2022 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of December 31, 2021 | $ | 320 | | | $ | 73 | | | $ | 105 | | | $ | 38 | | | $ | 104 | | | $ | 37 | | | $ | 18 | | | $ | 49 | |
Plus: Current period provision for expected credit losses(b) | 101 | | | 21 | | | 21 | | | 28 | | | 31 | | | 16 | | | 7 | | | 8 | |
Less: Write-offs, net of recoveries(a)(c) | 67 | | | 13 | | | 19 | | | 9 | | | 26 | | | 11 | | | 3 | | | 12 | |
| Balance as of June 30, 2022 | $ | 354 | | | $ | 81 | | | $ | 107 | | | $ | 57 | | | $ | 109 | | | $ | 42 | | | $ | 22 | | | $ | 45 | |
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| Six Months Ended June 30, 2021 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of December 31, 2020 | $ | 334 | | | $ | 97 | | | $ | 116 | | | $ | 35 | | | $ | 86 | | | $ | 32 | | | $ | 22 | | | $ | 32 | |
| Plus: Current period provision (benefit) for expected credit losses | 28 | | | 12 | | | 6 | | | (5) | | | 15 | | | 10 | | | 1 | | | 4 | |
Less: Write-offs, net of recoveries(a) | 42 | | | 20 | | | 11 | | | 3 | | | 8 | | | 4 | | | 4 | | | — | |
| Balance as of June 30, 2021 | $ | 320 | | | $ | 89 | | | $ | 111 | | | $ | 27 | | | $ | 93 | | | $ | 38 | | | $ | 19 | | | $ | 36 | |
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| Three Months Ended March 31, 2023 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of December 31, 2022 | $ | 327 | | | $ | 59 | | | $ | 105 | | | $ | 54 | | | $ | 109 | | | $ | 47 | | | $ | 21 | | | $ | 41 | |
Plus: Current period provision for expected credit losses(a) | 108 | | | 22 | | | 39 | | | 30 | | | 17 | | | 9 | | | 7 | | | 1 | |
Less: Write-offs, net of recoveries(b) | 46 | | | 7 | | | 14 | | | 11 | | | 14 | | | 7 | | | 2 | | | 5 | |
| Balance as of March 31, 2023 | $ | 389 | | | $ | 74 | | | $ | 130 | | | $ | 73 | | | $ | 112 | | | $ | 49 | | | $ | 26 | | | $ | 37 | |
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| Three Months Ended March 31, 2022 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of December 31, 2021 | $ | 320 | | | $ | 73 | | | $ | 105 | | | $ | 38 | | | $ | 104 | | | $ | 37 | | | $ | 18 | | | $ | 49 | |
| Plus: Current period provision for expected credit losses | 110 | | | 26 | | | 31 | | | 26 | | | 27 | | | 11 | | | 7 | | | 9 | |
| Less: Write-offs, net of recoveries | 41 | | | 7 | | | 11 | | | 5 | | | 18 | | | 8 | | | 1 | | | 9 | |
| Balance as of March 31, 2022 | $ | 389 | | | $ | 92 | | | $ | 125 | | | $ | 59 | | | $ | 113 | | | $ | 40 | | | $ | 24 | | | $ | 49 | |
__________
(a)For PECO and BGE, the change in current period provision for expected credit losses is primarily a result of increased aging of receivables.
(b)Recoveries were not material to the Registrants.
The following tables present the rollforward of Allowance for Credit Losses on Other Accounts Receivable.
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| Three Months Ended March 31, 2023 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of December 31, 2022 | $ | 82 | | | $ | 17 | | | $ | 9 | | | $ | 10 | | | $ | 46 | | | $ | 25 | | | $ | 7 | | | $ | 14 | |
| Plus: Current period provision for expected credit losses | 14 | | | 2 | | | 3 | | | 4 | | | 5 | | | 3 | | | 1 | | | 1 | |
Less: Write-offs, net of recoveries(a) | 5 | | | 1 | | | 1 | | | 2 | | | 1 | | | — | | | — | | | 1 | |
| Balance as of March 31, 2023 | $ | 91 | | | $ | 18 | | | $ | 11 | | | $ | 12 | | | $ | 50 | | | $ | 28 | | | $ | 8 | | | $ | 14 | |
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| Three Months Ended March 31, 2022 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of December 31, 2021 | $ | 72 | | | $ | 17 | | | $ | 7 | | | $ | 9 | | | $ | 39 | | | $ | 16 | | | $ | 8 | | | $ | 15 | |
| Plus: Current period provision for expected credit losses | 14 | | | 4 | | | 3 | | | 3 | | | 4 | | | 2 | | | 1 | | | 1 | |
| Less: Write-offs, net of recoveries | 5 | | | 1 | | | 1 | | | 1 | | | 2 | | | — | | | — | | | 2 | |
| Balance as of March 31, 2022 | $ | 81 | | | $ | 20 | | | $ | 9 | | | $ | 11 | | | $ | 41 | | | $ | 18 | | | $ | 9 | | | $ | 14 | |
__________
(a)Recoveries were not material to the Registrants.
(b)For BGE, Pepco, and ACE, the increase is primarily as a result of increased receivable balances due to the increased aging of receivables.
(c)
For ACE, the increase in 2022 is primarily related to the termination of the moratorium, which beginning in March 2020, prevented customer disconnections for non-payment. With disconnection activities restarting in January 2022, write-offs of aging accounts receivable increased throughout the year.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 6 — Accounts Receivable
The following tables present the rollforward of Allowance for Credit Losses on Other Accounts Receivable.
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| Three Months Ended June 30, 2022 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of March 31, 2022 | $ | 81 | | | $ | 20 | | | $ | 9 | | | $ | 11 | | | $ | 41 | | | $ | 18 | | | $ | 9 | | | $ | 14 | |
| Plus: Current period provision (benefit) for expected credit losses | 2 | | | (2) | | | 2 | | | 1 | | | 1 | | | 2 | | | (1) | | | — | |
Less: Write-offs, net of recoveries(a) | 2 | | | — | | | 1 | | | 1 | | | — | | | — | | | — | | | — | |
| Balance as of June 30, 2022 | $ | 81 | | | $ | 18 | | | $ | 10 | | | $ | 11 | | | $ | 42 | | | $ | 20 | | | $ | 8 | | | $ | 14 | |
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| Three Months Ended June 30, 2021 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of March 31, 2021 | $ | 79 | | | $ | 22 | | | $ | 11 | | | $ | 9 | | | $ | 37 | | | $ | 15 | | | $ | 10 | | | $ | 12 | |
| Plus: Current period (benefit) provision for expected credit losses | (5) | | | (3) | | | (3) | | | — | | | 1 | | | 1 | | | (1) | | | 1 | |
Less: Write-offs, net of recoveries(a) | 3 | | | 1 | | | 1 | | | 1 | | | — | | | — | | | — | | | — | |
| Balance as of June 30, 2021 | $ | 71 | | | $ | 18 | | | $ | 7 | | | $ | 8 | | | $ | 38 | | | $ | 16 | | | $ | 9 | | | $ | 13 | |
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| Six Months Ended June 30, 2022 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of December 31, 2021 | $ | 72 | | | $ | 17 | | | $ | 7 | | | $ | 9 | | | $ | 39 | | | $ | 16 | | | $ | 8 | | | $ | 15 | |
| Plus: Current period provision for expected credit losses | 15 | | | 2 | | | 4 | | | 4 | | | 5 | | | 4 | | | — | | | 1 | |
Less: Write-offs, net of recoveries(a) | 6 | | | 1 | | | 1 | | | 2 | | | 2 | | | — | | | — | | | 2 | |
| Balance as of June 30, 2022 | $ | 81 | | | $ | 18 | | | $ | 10 | | | $ | 11 | | | $ | 42 | | | $ | 20 | | | $ | 8 | | | $ | 14 | |
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| Six Months Ended June 30, 2021 |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Balance as of December 31, 2020 | $ | 71 | | | $ | 21 | | | $ | 8 | | | $ | 9 | | | $ | 33 | | | $ | 13 | | | $ | 9 | | | $ | 11 | |
| Plus: Current period provision (benefit) for expected credit losses | 5 | | | (2) | | | 1 | | | 1 | | | 5 | | | 3 | | | — | | | 2 | |
Less: Write-offs, net of recoveries(a) | 5 | | | 1 | | | 2 | | | 2 | | | — | | | — | | | — | | | — | |
| Balance as of June 30, 2021 | $ | 71 | | | $ | 18 | | | $ | 7 | | | $ | 8 | | | $ | 38 | | | $ | 16 | | | $ | 9 | | | $ | 13 | |
__________
(a)Recoveries were not material to the Registrants.
Unbilled Customer Revenue
The following table provides additional information about unbilled customer revenues recorded in the Registrants' Consolidated Balance Sheets as of June 30, 2022March 31, 2023 and December 31, 2021.2022.
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| Unbilled customer revenues(a) |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| June 30, 2022 | $ | 636 | | | $ | 191 | | | $ | 138 | | | $ | 123 | | | $ | 184 | | | $ | 94 | | | $ | 41 | | | $ | 49 | |
| December 31, 2021 | 747 | | | 240 | | | 161 | | | 171 | | | 175 | | | 82 | | | 53 | | | 40 | |
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| Unbilled customer revenues(a) |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| March 31, 2023 | $ | 709 | | | $ | 237 | | | $ | 149 | | | $ | 149 | | | $ | 174 | | | $ | 74 | | | $ | 49 | | | $ | 51 | |
| December 31, 2022 | 912 | | | 223 | | | 219 | | | 247 | | | 223 | | | 103 | | | 74 | | | 46 | |
__________
(a)Unbilled customer revenues are classified in Customer accounts receivables,receivable, net in the Registrants' Consolidated Balance Sheets.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 6 — Accounts Receivable
Other Purchases of Customer and Other Accounts Receivables
The Utility Registrants are required, under separate legislation and regulations in Illinois, Pennsylvania, Maryland, District of Columbia, Delaware, and New Jersey, to purchase certain receivables from alternative retail electric and, as applicable, natural gas suppliers that participate in the utilities' consolidated billing. The following table presents the total receivables purchased.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Total receivables purchased |
| Exelon(a) | | ComEd | | PECO | | BGE(a) | | PHI | | Pepco | | DPL | | ACE |
| Six months ended June 30, 2022 | $ | 1,911 | | | $ | 456 | | | $ | 518 | | | $ | 391 | | | $ | 546 | | | $ | 342 | | | $ | 104 | | | $ | 100 | |
| Six months ended June 30, 2021 | 1,838 | | | 485 | | | 507 | | | 343 | | | 503 | | | 310 | | | 103 | | | 90 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Total receivables purchased |
| Exelon(a) | | ComEd | | PECO | | BGE(a) | | PHI | | Pepco | | DPL | | ACE |
| Three months ended March 31, 2023 | $ | 1,108 | | | $ | 240 | | | $ | 309 | | | $ | 245 | | | $ | 314 | | | $ | 210 | | | $ | 56 | | | $ | 48 | |
| Three months ended March 31, 2022 | 1,044 | | | 248 | | | 292 | | | 222 | | | 282 | | | 174 | | | 57 | | | 51 | |
__________(a)Includes $4 million of receivables purchased from Generation prior to the separation on February 1, 2022 for the sixthree months ended June 30, 2022 and $15 million of receivables purchased from Generation for the six months ended June 30, 2021.March 31, 2022.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 7 — Income Taxes
7. Income Taxes (All Registrants)
Rate Reconciliation
The effective income tax rate from continuing operations varies from the U.S. federal statutory rate principally due to the following:
| | | | Three Months Ended June 30, 2022(a) | | | Three Months Ended March 31, 2023(a) | |
| | Exelon | | ComEd | | PECO(b) | | BGE(b) | | PHI | | Pepco(b) | | DPL | | ACE(b) | | | Exelon | | ComEd | | PECO(b) | | BGE | | PHI | | Pepco | | DPL | | ACE | |
| U.S. Federal statutory rate | U.S. Federal statutory rate | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | U.S. Federal statutory rate | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | |
| Increase (decrease) due to: | Increase (decrease) due to: | | | Increase (decrease) due to: | | |
State income taxes, net of Federal income tax benefit(c) | (5.4) | | | 7.9 | | | (0.6) | | | 2.1 | | | 1.5 | | | (3.4) | | | 7.2 | | | 6.7 | | | |
| State income taxes, net of Federal income tax benefit | | State income taxes, net of Federal income tax benefit | 6.0 | | | 7.9 | | | (1.4) | | | 6.4 | | | 6.0 | | | 5.4 | | | 6.3 | | | 6.9 | | |
| Plant basis differences | Plant basis differences | (3.3) | | | (0.5) | | | (11.0) | | | (1.3) | | | (1.7) | | | (2.4) | | | (0.7) | | | (1.0) | | | Plant basis differences | (4.0) | | | (0.3) | | | (15.2) | | | (0.7) | | | (1.8) | | | (2.5) | | | (1.0) | | | (0.9) | | |
| Excess deferred tax amortization | Excess deferred tax amortization | (10.5) | | | (5.5) | | | (3.1) | | | (19.0) | | | (19.2) | | | (15.7) | | | (20.0) | | | (24.5) | | | Excess deferred tax amortization | (6.3) | | | (5.7) | | | (2.4) | | | (5.4) | | | (7.0) | | | (8.4) | | | (8.8) | | | (2.0) | | |
| Amortization of investment tax credit, including deferred taxes on basis difference | Amortization of investment tax credit, including deferred taxes on basis difference | (0.1) | | | (0.1) | | | — | | | (0.1) | | | (0.1) | | | — | | | (0.2) | | | (0.2) | | | Amortization of investment tax credit, including deferred taxes on basis difference | (0.1) | | | (0.1) | | | — | | | (0.1) | | | (0.1) | | | — | | | (0.1) | | | (0.1) | | |
| Tax credits | Tax credits | (0.4) | | | (0.3) | | | — | | | (1.5) | | | (0.4) | | | (0.4) | | | (0.4) | | | (0.4) | | | Tax credits | (0.5) | | | (0.3) | | | — | | | (0.5) | | | (0.4) | | | (0.4) | | | (0.4) | | | (0.3) | | |
Other(d) | 7.7 | | | — | | | — | | | 1.4 | | | (0.1) | | | (0.5) | | | 1.8 | | | (1.6) | | | |
| Other | | Other | 0.6 | | | 0.3 | | | 0.4 | | | (0.1) | | | 0.3 | | | 0.5 | | | (0.3) | | | 0.4 | | |
| Effective income tax rate | Effective income tax rate | 9.0 | % | | 22.5 | % | | 6.3 | % | | 2.6 | % | | 1.0 | % | | (1.4) | % | | 8.7 | % | | — | % | | Effective income tax rate | 16.7 | % | | 22.8 | % | | 2.4 | % | | 20.6 | % | | 18.0 | % | | 15.6 | % | | 16.7 | % | | 25.0 | % | |
| | | | Three Months Ended June 30, 2021(a) | | Three Months Ended March 31, 2022(a) |
| | Exelon | | ComEd | | PECO(e) | | BGE(e) | | PHI | | Pepco(e) | | DPL | | ACE(e) | | Exelon | | ComEd | | PECO(c) | | BGE(c) | | PHI | | Pepco(c) | | DPL | | ACE(c) |
| U.S. Federal statutory rate | U.S. Federal statutory rate | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | U.S. Federal statutory rate | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % |
| Increase (decrease) due to: | Increase (decrease) due to: | | Increase (decrease) due to: | |
| State income taxes, net of Federal income tax benefit | 1.1 | | | 8.0 | | | (2.9) | | | (12.5) | | | 2.4 | | | (2.1) | | | 7.0 | | | 8.1 | | |
State income taxes, net of Federal income tax benefit(d) | | State income taxes, net of Federal income tax benefit(d) | 21.1 | | | 8.0 | | | (0.1) | | | 2.4 | | | 3.7 | | | (4.5) | | | 6.2 | | | 6.8 | |
| Plant basis differences | Plant basis differences | (4.0) | | | (0.7) | | | (12.5) | | | (2.3) | | | (1.1) | | | (1.5) | | | (0.7) | | | (0.6) | | Plant basis differences | (3.6) | | | (0.6) | | | (11.3) | | | (0.9) | | | (1.6) | | | (2.6) | | | (0.7) | | | (1.3) | |
| Excess deferred tax amortization | Excess deferred tax amortization | (13.4) | | | (7.0) | | | (3.3) | | | (17.5) | | | (22.3) | | | (19.0) | | | (21.9) | | | (28.2) | | Excess deferred tax amortization | (11.5) | | | (6.3) | | | (3.2) | | | (17.6) | | | (17.7) | | | (17.4) | | | (19.4) | | | (22.2) | |
| Amortization of investment tax credit, including deferred taxes on basis difference | Amortization of investment tax credit, including deferred taxes on basis difference | (0.1) | | | (0.1) | | | — | | | (0.1) | | | (0.1) | | | — | | | (0.2) | | | (0.2) | | Amortization of investment tax credit, including deferred taxes on basis difference | (0.1) | | | (0.1) | | | — | | | (0.1) | | | (0.1) | | | — | | | (0.2) | | | (0.2) | |
| Tax credits | (1.0) | | | (0.8) | | | — | | | (3.6) | | | (0.8) | | | (0.7) | | | (0.9) | | | (0.6) | | |
| Other | (2.7) | | | (1.1) | | | (0.4) | | | (6.6) | | | (1.3) | | | (1.9) | | | (1.1) | | | (2.3) | | |
Tax credits(e) | | Tax credits(e) | 1.7 | | | (0.3) | | | — | | | (0.4) | | | (0.4) | | | (0.4) | | | (0.3) | | | (0.3) | |
Other(f) | | Other(f) | 2.6 | | | — | | | — | | | (0.1) | | | 0.2 | | | (0.6) | | | 0.1 | | | (0.1) | |
| Effective income tax rate | Effective income tax rate | 0.9 | % | | 19.3 | % | | 1.9 | % | | (21.6) | % | | (2.2) | % | | (4.2) | % | | 3.2 | % | | (2.8) | % | Effective income tax rate | 31.2 | % | | 21.7 | % | | 6.4 | % | | 4.3 | % | | 5.1 | % | | (4.5) | % | | 6.7 | % | | 3.7 | % |
__________
(a)Positive percentages represent income tax expense. Negative percentages represent income tax benefit.
(b)For PECO, the lower effective tax rate is primarily related to plant basis differences attributable to tax repair deductions.
(c)For PECO, the lower effective tax rate is primarily related to plant basis differences attributable to tax repair deductions. For BGE, the lower effective tax rate is primarily due to the Maryland multi-year plan which resulted in the acceleration of certain income tax benefits. For Pepco, the income tax benefit is primarily due to the Maryland and Washington, D.C. multi-year plans which resulted in the acceleration of certain income tax benefits. For ACE, the lower effective tax rate is primarily duerelated to the acceleration of certain income tax benefits due to distribution rate case settlements.
(c)(d)For Exelon, the lowerhigher state income taxes, net of federal income tax benefit, is primarily due to the long-term marginal state income tax rate change of approximately $67 million and the recognition of a valuation allowance of approximately $40 million against the net deferred tax asset position for certain standalone state filing jurisdiction as a result of the separation.
(e)For Exelon, reflects the income tax expense related to a one-time impact associated with a statethe write-off of federal tax benefitcredits subject to recapture of $43 million and indemnification adjustments pursuant to the Tax Matters Agreement of $5approximately $15 million as a result of the separation.
(d)(f)For Exelon, primarily related to indemnification adjustments pursuant toreflects the Tax Matters Agreementnondeductible transaction costs of $48 million.
(e)For PECO,approximately $19 million arising as part of the lower effective tax rate is primarily related to plant basis differences attributable to tax repair deductions. For BGE, the income tax benefit is primarily due to the Maryland multi-year plan which resulted in the acceleration of certain income tax benefits. For Pepco, the income tax benefit is primarily due to the Maryland multi-year plan which resulted in the acceleration of certain income tax benefits. For ACE, the lower effective tax rate is primarily due to the acceleration of certain income tax benefits due to distribution rate case settlements.separation.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 7 — Income Taxes
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2022(a) | |
| Exelon | | ComEd | | PECO(b) | | BGE(b) | | PHI | | Pepco(b) | | DPL | | ACE(b) | |
| U.S. Federal statutory rate | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | |
| Increase (decrease) due to: | | | | | | | | | | | | | | | | |
State income taxes, net of Federal income tax benefit(c) | 9.9 | | | 7.9 | | | (0.3) | | | 2.3 | | | 2.8 | | | (3.8) | | | 6.5 | | | 6.7 | | |
| Plant basis differences | (3.5) | | | (0.5) | | | (11.2) | | | (1.0) | | | (1.7) | | | (2.5) | | | (0.7) | | | (1.2) | | |
| Excess deferred tax amortization | (11.0) | | | (5.8) | | | (3.2) | | | (17.8) | | | (18.3) | | | (16.3) | | | (19.5) | | | (22.9) | | |
| Amortization of investment tax credit, including deferred taxes on basis difference | (0.1) | | | (0.1) | | | — | | | (0.1) | | | (0.1) | | | — | | | (0.2) | | | (0.2) | | |
Tax credits(d) | 0.8 | | | (0.3) | | | — | | | (0.6) | | | (0.4) | | | (0.4) | | | (0.3) | | | (0.3) | | |
Other(e) | 4.7 | | | 0.1 | | | 0.3 | | | 0.3 | | | 0.1 | | | (0.7) | | | 0.4 | | | (0.5) | | |
| Effective income tax rate | 21.8 | % | | 22.3 | % | | 6.6 | % | | 4.1 | % | | 3.4 | % | | (2.7) | % | | 7.2 | % | | 2.6 | % | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2021(a) |
| Exelon | | ComEd | | PECO(f) | | BGE(f) | | PHI | | Pepco(f) | | DPL | | ACE(f) |
| U.S. Federal statutory rate | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % | | 21.0 | % |
| Increase (decrease) due to: | | | | | | | | | | | | | | | |
| State income taxes, net of Federal income tax benefit | 2.0 | | | 7.4 | | | (2.1) | | | (10.5) | | | 4.2 | | | 1.5 | | | 6.6 | | | 7.8 | |
| Plant basis differences | (3.6) | | | (0.6) | | | (11.3) | | | (1.6) | | | (1.3) | | | (1.8) | | | (0.7) | | | (0.7) | |
| Excess deferred tax amortization | (12.5) | | | (7.0) | | | (3.3) | | | (15.9) | | | (20.8) | | | (17.2) | | | (19.7) | | | (28.3) | |
| Amortization of investment tax credit, including deferred taxes on basis difference | (0.1) | | | (0.1) | | | — | | | (0.1) | | | (0.1) | | | — | | | (0.2) | | | (0.2) | |
| Tax credits | (0.5) | | | (0.5) | | | — | | | (0.9) | | | (0.5) | | | (0.5) | | | (0.4) | | | (0.5) | |
| Other | (1.6) | | | (2.3) | | | (0.1) | | | (1.0) | | | (0.7) | | | (0.8) | | | (0.1) | | | (1.1) | |
| Effective income tax rate | 4.7 | % | | 17.9 | % | | 4.2 | % | | (9.0) | % | | 1.8 | % | | 2.2 | % | | 6.5 | % | | (2.0) | % |
__________
(a)Positive percentages represent income tax expense. Negative percentages represent income tax benefit.
(b)For PECO, the lower effective tax rate is primarily related to plant basis differences attributable to tax repair deductions. For BGE, the lower effective tax rate is primarily due to the Maryland multi-year plan which resulted in the acceleration of certain income tax benefits. For Pepco, the income tax benefit is primarily due to the Maryland and Washington, D.C. multi-year plans which resulted in the acceleration of certain income tax benefits. For ACE, the lower effective tax rate is primarily due to the acceleration of certain income tax benefits due to distribution rate case settlements.
(c)For Exelon, the higher state income taxes, net of federal income tax benefit, is primarily due to the long-term marginal state income tax rate change of $67 million and the recognition of a valuation allowance of $40 million against the net deferred tax asset position for certain standalone state filing jurisdictions, partially offset by a one-time impact associated with a state tax benefit of $43 million and indemnification adjustments pursuant to the Tax Matters Agreement of $4 million as a result of the separation.
(d)For Exelon, reflects the income tax expense related to the write-off of federal tax credits subject to recapture of $15 million as a result of the separation.
(e)For Exelon, primarily reflects the nondeductible transaction costs of approximately $19 million arising as part of the separation and indemnification adjustments pursuant to the Tax Matters Agreement of $48 million.
(f)For PECO, the lower effective tax rate is primarily related to plant basis differences attributable to tax repair deductions. For BGE, the income tax benefit is primarily due to the Maryland multi-year plan which resulted in the acceleration of certain income tax benefits. For Pepco, the income tax benefit is primarily due to the Maryland multi-year plan which resulted in the acceleration of certain income tax benefits. For ACE, the lower effective tax rate is primarily due to the acceleration of certain income tax benefits due to distribution rate case settlements.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 7 — Income Taxes
Unrecognized Tax Benefits
Exelon, PHI and ACE have the following unrecognized tax benefits as of June 30, 2022March 31, 2023 and December 31, 2021.2022. ComEd's, PECO's, BGE's, Pepco's, and DPL's amounts are not material.
| | | | | | | | | | | | | | | | | | | |
| Exelon(a) | | | | PHI | | ACE |
| June 30, 2022 | $ | 147 | | | | | $ | 58 | | | $ | 16 | |
| December 31, 2021 | 143 | | | | | 56 | | | 16 | |
| | | | | | | | | | | | | | | | | | | |
| Exelon(a) | | | | PHI | | ACE |
| March 31, 2023 | $ | 148 | | | | | $ | 59 | | | $ | 17 | |
| December 31, 2022 | 148 | | | | | 59 | | | 17 | |
__________(a)As of June 30,March 31, 2023 and December 31, 2022, Exelon recorded a receivable of $50 million in NoncurrentOther deferred debits and other assets in the Consolidated Balance Sheet for Constellation’s share of unrecognized tax benefits for periods prior to the separation.
Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date
As of June 30, 2022,March 31, 2023, ACE has $14 million of unrecognized state tax benefits that could significantly decrease within the 12 months after the reporting date based on the outcome of pending court cases involving other taxpayers. The unrecognized tax benefit, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate.
Other Tax Matters
Separation (Exelon)
In the first quarter of 2022, in connection with the separation, Exelon recorded an income tax expense related to continuing operations of $148 million primarily due to the long-term marginal state income tax rate change of $67 million discussed further below, the recognition of valuation allowances of approximately $40 million against the net deferred tax assets positions for certain standalone state filing jurisdictions, the write-off of federal and state tax credits subject to recapture of $17 million, and nondeductible transaction costs for federal and state taxes of $24 million.
Tax Matters Agreement (Exelon)
In connection with the separation, Exelon entered into a TMA with Constellation. The TMA governs the respective rights, responsibilities, and obligations between Exelon and Constellation after the separation with respect to tax liabilities, refunds and attributes for open tax years that Constellation was part of Exelon’s consolidated group for U.S. federal, state, and local tax purposes.
Indemnification for Taxes. As a former subsidiary of Exelon, Constellation has joint and several liability with Exelon to the IRS and certain state jurisdictions relating to the taxable periods prior to the separation. The TMA specifies that Constellation is liable for their share of taxes required to be paid by Exelon with respect to taxable periods prior to the separation to the extent Constellation would have been responsible for such taxes under the existing Exelon tax sharing agreement. As a result,of March 31, 2023, Exelon recorded a receivablepayable of $55$18 million in Current other assets in the Consolidated Balance Sheet for Constellation’s share of taxes for periods priorOther current liabilities that is due to the separation, as of March 31, 2022. As of June 30, 2022, the remaining amount of the receivable is $31 million.Constellation.
Tax Refunds. The TMA specifies that Constellation is entitled to their share of any future tax refunds claimed by Exelon with respect to taxable periods prior to the separation to the extent that Constellation would have received such tax refunds under the existing Exelon tax sharing agreement.
Tax Attributes. At the date of separation certain tax attributes, primarily pre-closing tax credit carryforwards, that were generated by Constellation were required by law to be allocated to Exelon. The TMA also provides that Exelon will reimburse Constellation when those allocated tax credit carryforwards are utilized. As of March 31, 2022,2023, Exelon recorded a payable of $11$212 million and $484$319 million in Current otherOther current liabilities and NoncurrentOther deferred credits and other liabilities, respectively, in the Consolidated Balance Sheet for tax creditattribute carryforwards that are expected to be utilized and reimbursed to Constellation. As of June 30,
Corporate Alternative Minimum Tax (All Registrants)
On August 16, 2022, the currentIRA was signed into law and noncurrent payable amountsimplements a new corporate alternative minimum tax (CAMT) that imposes a 15.0% tax on modified GAAP net income. Corporations are $0 millionentitled to a tax credit (minimum tax credit) to the extent the CAMT liability exceeds the regular tax liability. This amount can be carried forward indefinitely and $480 million, respectively.used in future years when regular tax exceeds the CAMT.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 7 — Income Taxes
Long-Term Marginal StateBeginning in 2023, Exelon and each of the Utility Registrants will be subject to and will report the CAMT on a separate Registrant basis in the Consolidated Statements of Operations and Comprehensive Income Tax Rate (All Registrants)
Inand the first quarter of 2022, Exelon updated its marginal state incomeConsolidated Balance Sheets. The deferred tax rates for changes in state apportionment dueasset related to the separation, which resulted in an increase of $67 millionminimum tax credit carryforward will be realized to the extent Exelon’s consolidated deferred tax liability at Exelon, and a corresponding adjustment to incomeliabilities exceed the minimum tax expense, net of federal taxes.
Pennsylvania Corporate Income Tax Rate Change (Exelon and PECO)
On July 8, 2022, Pennsylvania enacted House Bill 1342, which will permanently reduce the corporate incomecredit carryforward. Exelon’s deferred tax rate from 9.99% to 4.99%. The tax rate will be reduced to 8.99% for the 2023 tax year. Starting with the 2024 tax year, the rate is reduced by 0.50% annually until it reaches 4.99% in 2031. As a result of the rate change, in the third quarter of 2022, Exelon and PECO will record an estimated one-time decrease to deferred income taxes of $390 million with a corresponding decrease to the deferred income taxes regulatory asset of $428 million for the amounts thatliabilities are expected to be settled throughexceed the minimum tax credit carryforward for the foreseeable future customer rates and an increasethus no valuation allowance is required. Exelon is continuing to income tax expenseassess the financial statement impacts of $38 million (net of federal taxes). The tax rate decrease is not expected to have a material ongoing impact to Exelon’sthe IRA and PECO’s financial statements.will update estimates based on future guidance issued by the U.S. Treasury.
8. Retirement Benefits (All Registrants)
Defined Benefit Pension and OPEB
Effective February 1, 2022, in connection with the separation, pension and OPEB obligations and assets for current and former employees of the Constellation business and certain other former employees of Exelon and its subsidiaries transferred to pension and OPEB plans and trusts maintained by Constellation or its subsidiaries. The Exelon New England Union Employees Pension Plan and Constellation Mystic Power, LLC Union Employees Pension Plan Including Plan A and Plan B were transferred. The following OPEB plans were also transferred: Constellation Mystic Power, LLC Post-Employment Medical Account Savings Plan, Exelon New England Union Post-Employment Medical Savings Account Plan, and the Nine Mile Point Nuclear Station, LLC Medical Care and Prescription Drug Plan for Retired Employees.
As a result of the separation, Exelon restructured certain of its qualified pension plans. Pension obligations and assets for current and former employees continuing with Exelon and who are participants in the Exelon Employee Pension Plan for Clinton, TMI, and Oyster Creek, Pension Plan of Constellation Energy Nuclear Group, LLC, and Nine Mile Point Pension Plan were merged into the Pension Plan of Constellation Energy Group, Inc, which was subsequently renamed, Exelon Pension Plan (EPP). Exelon employees who participated in these plans prior to the separation now participate in the EPP. The merging of the plans did not change the benefits offered to the plan participants and, thus, had no impact on Exelon's pension obligations.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 8 — Retirement Benefits
The tables below show the pension and OPEB plans in which employees of each operating company participated as of June 30, 2022:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | Operating Company(a)
|
Name of Plan: | | | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
Qualified Pension Plans: | | | | | | | | | | | | | | | | |
Exelon Corporation Retirement Program | | | | X | | X | | X | | X | | X | | X | | X |
Exelon Corporation Pension Plan for Bargaining Unit Employees | | | | X | | | | | | | | | | | | |
Exelon Pension Plan | | | | X | | X | | X | | X | | X | | X | | X |
Pepco Holdings LLC Retirement Plan | | | | X | | X | | X | | X | | X | | X | | X |
Non-Qualified Pension Plans: | | | | | | | | | | | | | | | | |
Exelon Corporation Supplemental Pension Benefit Plan and 2000 Excess Benefit Plan | | | | X | | X | | | | X | | | | | | |
Exelon Corporation Supplemental Management Retirement Plan | | | | X | | X | | X | | X | | | | X | | |
Constellation Energy Group, Inc. Senior Executive Supplemental Plan | | | | | | | | X | | X | | | | | | |
Constellation Energy Group, Inc. Supplemental Pension Plan | | | | | | | | X | | X | | | | | | |
Constellation Energy Group, Inc. Benefits Restoration Plan | | | | | | X | | X | | X | | | | | | |
Baltimore Gas & Electric Company Executive Benefit Plan | | | | | | | | X | | | | | | | | |
Baltimore Gas & Electric Company Manager Benefit Plan | | | | | | X | | X | | | | | | | | |
Pepco Holdings LLC 2011 Supplemental Executive Retirement Plan | | | | | | | | | | X | | X | | X | | X |
Conectiv Supplemental Executive Retirement Plan | | | | | | | | | | X | | | | X | | X |
Pepco Holdings LLC Combined Executive Retirement Plan | | | | | | | | | | X | | X | | | | |
Atlantic City Electric Director Retirement Plan | | | | | | | | | | X | | | | | | X |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 8 — Retirement Benefits
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | Operating Company(a)
|
Name of Plan: | | | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
OPEB Plans: | | | | | | | | | | | | | | | | |
PECO Energy Company Retiree Medical Plan | | | | X | | X | | X | | X | | X | | X | | X |
Exelon Corporation Health Care Program | | | | X | | X | | X | | X | | X | | X | | X |
Exelon Corporation Employees’ Life Insurance Plan | | | | X | | X | | X | | | | | | | | |
Exelon Corporation Health Reimbursement Arrangement Plan | | | | X | | X | | X | | | | | | | | |
BGE Retiree Medical Plan | | | | X | | X | | X | | X | | X | | X | | |
BGE Retiree Dental Plan | | | | | | | | X | | | | | | | | |
Exelon Employee Life Insurance Plan and Family Life Insurance Plan | | | | X | | | | X | | X | | X | | X | | |
Exelon Retiree Medical Plan of Constellation Energy Nuclear Group, LLC | | | | X | | | | X | | X | | | | | | |
Exelon Retiree Dental Plan of Constellation Energy Nuclear Group, LLC | | | | X | | | | X | | X | | | | | | |
Pepco Holdings LLC Welfare Plan for Retirees | | | | X | | X | | X | | X | | X | | X | | X |
__________
(a)Employees generally remain in their legacy benefit plans when transferring between operating companies.
As of February 1, 2022, in connection with the separation, Exelon's pension and OPEB plans were remeasured. The remeasurement and separation resulted in a decrease to the pension obligation, net of plan assets, of $921 million and a decrease to the OPEB obligation of $893 million. Additionally, accumulated other comprehensive loss, decreased by $1,994 million (after-tax) and regulatory assets and liabilities increased by $14 million and $5 million respectively. Key assumptions were held consistent with the year end December 31, 2021 assumptions with the exception of the discount rate.
The majority of the 20222023 pension benefit cost for the Exelon-sponsored plans is calculated using an expected long-term rate of return on plan assets of 7.00% and a discount rate of 3.24%5.53%. The majority of the 20222023 OPEB cost is calculated using an expected long-term rate of return on plan assets of 6.44%6.50% for funded plans and a discount rate of 3.20%5.51%.
During the first quarter of 2022,2023, Exelon received an updated valuation of its pension and OPEB to reflect actual census data as of FebruaryJanuary 1, 2022.2023. This valuation resulted in a decreasean increase to the pension obligation of $24$27 million and an increase to the OPEB obligation of $5$2 million. Additionally, accumulated other comprehensive lossAOCI increased by $5$10 million (after-tax) and regulatory assets and liabilities decreasedincreased by $30$18 million and $3$1 million, respectively.
A portion of the net periodic benefit cost for all plans is capitalized within the Consolidated Balance Sheets. The following table presents the components of Exelon's net periodic benefit costs, prior to capitalization, for the three and six months ended June 30, 2022March 31, 2023 and 2021.2022.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 8 — Retirement Benefits
| | | | | | Pension Benefits | | OPEB | | | Pension Benefits | | OPEB | |
| | Three Months Ended June 30, | | Three Months Ended June 30, | | | Three Months Ended March 31, | | Three Months Ended March 31, | |
| | 2022 | | 2021 | | 2022 | | 2021 | | | 2023 | | 2022 | | 2023 | | 2022 | |
| Components of net periodic benefit cost: | Components of net periodic benefit cost: | | | | | | | | | Components of net periodic benefit cost: | | | | | | | | |
| Service cost | Service cost | $ | 58 | | | $ | 75 | | | $ | 10 | | | $ | 13 | | | Service cost | $ | 39 | | | $ | 61 | | | $ | 6 | | | $ | 10 | | |
| Interest cost | Interest cost | 110 | | | 101 | | | 19 | | | 17 | | | Interest cost | 145 | | | 110 | | | 25 | | | 19 | | |
| Expected return on assets | Expected return on assets | (205) | | | (210) | | | (25) | | | (25) | | | Expected return on assets | (189) | | | (209) | | | (21) | | | (25) | | |
| Amortization of: | Amortization of: | | | Amortization of: | | |
| Prior service cost (credit) | Prior service cost (credit) | 1 | | | — | | | (5) | | | (7) | | | Prior service cost (credit) | 1 | | | 1 | | | (2) | | | (5) | | |
| Actuarial loss | Actuarial loss | 73 | | | 99 | | | 4 | | | 8 | | | Actuarial loss | 41 | | | 76 | | | — | | | 4 | | |
| | Net periodic benefit cost | Net periodic benefit cost | $ | 37 | | | $ | 65 | | | $ | 3 | | | $ | 6 | | | Net periodic benefit cost | $ | 37 | | | $ | 39 | | | $ | 8 | | | $ | 3 | | |
| | Pension Benefits | | OPEB | | |
| Six Months Ended June 30, | | Six Months Ended June 30, | | |
| 2022 | | 2021 | | 2022 | | 2021 | | |
| Components of net periodic benefit cost: | | | | | | | | | |
| Service cost | $ | 119 | | | $ | 148 | | | $ | 20 | | | $ | 26 | | | |
| Interest cost | 220 | | | 202 | | | 38 | | | 35 | | | |
| Expected return on assets | (414) | | | (421) | | | (50) | | | (50) | | | |
| Amortization of: | | | |
| Prior service cost (credit) | 2 | | | 1 | | | (10) | | | (13) | | | |
| Actuarial loss | 149 | | | 199 | | | 8 | | | 14 | | | |
| Curtailment benefits | — | | | — | | | — | | | (1) | | | |
| | Net periodic benefit cost | $ | 76 | | | $ | 129 | | | $ | 6 | | | $ | 11 | | | |
The amounts below represent the Registrants' allocated pension and OPEB costs. For Exelon, the service cost component is included in Operating and maintenance expense and Property, plant, and equipment, net while the non-service cost components are included in Other, net and Regulatory assets. For the Utility Registrants, which apply multi-employer accounting, the service cost and non-service cost components are included in Operating and maintenance expense and Property, plant, and equipment, net in their consolidated financial statements.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 8 — Retirement Benefits
| | | | | Three Months Ended June 30, | | Six Months Ended June 30, | | | Three Months Ended March 31, |
| Pension and OPEB Costs (Benefit) | Pension and OPEB Costs (Benefit) | | 2022 | | 2021 | | 2022 | | 2021 | Pension and OPEB Costs (Benefit) | | 2023 | | 2022 |
| Exelon | Exelon | | $ | 40 | | | $ | 71 | | | $ | 82 | | | $ | 140 | | Exelon | | $ | 45 | | | $ | 42 | |
| ComEd | ComEd | | 14 | | | 32 | | | 30 | | | 64 | | ComEd | | 6 | | | 16 | |
| PECO | PECO | | (2) | | | 2 | | | (4) | | | 4 | | PECO | | (3) | | | (2) | |
| BGE | BGE | | 11 | | | 16 | | | 22 | | | 31 | | BGE | | 14 | | | 11 | |
| PHI | PHI | | 13 | | | 12 | | | 26 | | | 24 | | PHI | | 24 | | | 13 | |
| Pepco | Pepco | | 2 | | | 2 | | | 4 | | | 3 | | Pepco | | 8 | | | 2 | |
| DPL | DPL | | 1 | | | 1 | | | 2 | | | 1 | | DPL | | 4 | | | 1 | |
| ACE | ACE | | 3 | | | 3 | | | 6 | | | 5 | | ACE | | 4 | | | 3 | |
Defined Contribution Savings Plan
The Registrants participate in a 401(k) defined contribution savings plan that is sponsored by Exelon. The plan is qualified under applicable sections of the IRC and allowallows employees to contribute a portion of their pre-tax and/or after-tax income in accordance with specified guidelines. All Registrants match a percentage of the employee contributions up to certain limits. The following table presents the employer contributions and employer matching contributions to the savings plan for the three and six months ended June 30, 2022March 31, 2023 and 2021, respectively.2022.
| | | Three Months Ended June 30, | | Six Months Ended June 30, | | | Three Months Ended March 31, |
| Savings Plan Matching Contributions | | 2022 | | 2021 | | 2022 | | 2021 | |
| Savings Plan Employer Contributions | | Savings Plan Employer Contributions | | 2023 | | 2022 |
| Exelon | Exelon | | $ | 23 | | | $ | 23 | | | $ | 43 | | | $ | 43 | | Exelon | | $ | 21 | | | $ | 20 | |
| ComEd | ComEd | | 10 | | | 10 | | | 18 | | | 18 | | ComEd | | 9 | | | 8 | |
| PECO | PECO | | 3 | | | 3 | | | 6 | | | 6 | | PECO | | 3 | | | 3 | |
| BGE | BGE | | 3 | | | 2 | | | 5 | | | 4 | | BGE | | 2 | | | 2 | |
| PHI | PHI | | 4 | | | 4 | | | 7 | | | 7 | | PHI | | 3 | | | 3 | |
| Pepco | Pepco | | 1 | | | 1 | | | 2 | | | 2 | | Pepco | | 1 | | | 1 | |
| DPL | DPL | | 1 | | | 1 | | | 2 | | | 2 | | DPL | | 1 | | | 1 | |
| ACE | ACE | | 1 | | | 1 | | | 1 | | | 1 | | ACE | | — | | | — | |
9. Derivative Financial Instruments (All Registrants)
The Registrants use derivative instruments to manage commodity price risk and interest rate risk related to ongoing business operations. The Registrants do not execute derivatives for speculative or proprietary trading purposes.
Authoritative guidance requires that derivative instruments be recognized as either assets or liabilities at fair value, with changes in fair value of the derivative recognized in earnings immediately. Other accounting treatments are available through special election and designation, provided they meet specific, restrictive criteria both at the time of designation and on an ongoing basis. These alternative permissible accounting treatments include NPNS, cash flow hedges, and fair value hedges. At ComEd, derivative economic hedges related to commodities are recorded at fair value and offset by a corresponding regulatory asset or liability. At Exelon, derivative economic hedges related to interest rates are recorded at fair value and offsets are recorded to Electric operating revenues or Interest expense based on the activity the transaction is economically hedging. For all NPNS derivative instruments, accounts receivable or accounts payable are recorded when derivatives settle and revenue or expense is recognized in earnings as the underlying physical commodity is sold or consumed. At Exelon, derivative hedges that qualify and are designated as cash flow hedges are recorded at fair value and offsets are recorded to AOCI.
ComEd’s use of cash collateral is generally unrestricted unless ComEd is downgraded below investment grade. Cash collateral held by PECO, BGE, Pepco, DPL, and ACE must be deposited in an unaffiliated major U.S. commercial bank or foreign bank with a U.S. branch office that meetmeets certain qualifications.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 9 — Derivative Financial Instruments
Commodity Price Risk
The Registrants employ established policies and procedures to manage their risks associated with market fluctuations in commodity prices by entering into physical and financial derivative contracts, which are either determined to be non-derivative or classified as economic hedges. The Utility Registrants procure electric and natural gas supply through a competitive procurement process approved by each of the respective state utility commissions. The Utility Registrants’ hedging programs are intended to reduce exposure to energy and natural
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 9 — Derivative Financial Instruments
gas price volatility and have no direct earnings impact as the costs are fully recovered from customers through regulatory-approved recovery mechanisms. The following table provides a summary of the Utility Registrants’ primary derivative hedging instruments, listed by commodity and accounting treatment.
| | | | | | | | | | | |
| Registrant | Commodity | Accounting Treatment | Hedging Instrument |
| ComEd | Electricity | NPNS | Fixed price contracts based on all requirements in the IPA procurement plans. |
| Electricity | Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability(a) | 20-year floating-to-fixed energy swap contracts beginning June 2012 based on the renewable energy resource procurement requirements in the Illinois Settlement Legislation of approximately 1.3 million MWhs per year. |
| PECO | Electricity | NPNS | Fixed price contracts for default supply requirements through full requirements contracts. |
| Gas | NPNS | Fixed price contracts to cover about 10% of planned natural gas purchases in support of projected firm sales. |
| BGE | Electricity | NPNS | Fixed price contracts for all SOS requirements through full requirements contracts. |
| Gas | NPNS | Fixed price contracts for between 10-20% of forecasted system supply requirements for flowing (i.e., non-storage) gas for the November through March period. |
| Pepco | Electricity | NPNS | Fixed price contracts for all SOS requirements through full requirements contracts. |
| DPL | Electricity | NPNS | Fixed price contracts for all SOS requirements through full requirements contracts. |
| Gas | NPNS | Fixed and index priced contracts through full requirements contracts. |
| Gas | Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability(b) | Exchange traded future contracts for up to 50% of estimated monthly purchase requirements each month, including purchases for storage injections. |
| ACE | Electricity | NPNS | Fixed price contracts for all BGS requirements through full requirements contracts. |
__________
(a)See Note 3 — Regulatory Matters of the 2021 Recast2022 Form 10-K for additional information.
(b)The fair value of the DPL economic hedge is not material as of June 30, 2022March 31, 2023 and December 31, 2021.
The fair value of derivative economic hedges is presented in Other current assets and current and noncurrent Mark-to-market derivative liabilities in Exelon's and ComEd's Consolidated Balance Sheets. The Mark-to-market derivative assets included
Interest Rate and Other Risk (Exelon)
Exelon Corporate uses a combination of fixed-rate and variable-rate debt to manage interest rate exposure. Exelon Corporate may utilize interest rate derivatives to lock in Other current assetsrate levels in Exelon’santicipation of future financings, which are typically designated as cash flow hedges. In addition, Exelon Corporate may also utilize interest rate swaps to manage interest rate exposure and ComEd’s Consolidated Balance Sheets were $15 million and nonemanage potential fluctuations in Electric operating revenues at the corporate level in consolidation, which are directly correlated to yields on U.S. Treasury bonds under ComEd's distribution formula rate. These interest rate swaps are accounted for as economic hedges. A hypothetical 50
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 9 — Derivative Financial Instruments
basis point change in the interest rates associated with Exelon's interest rate swaps as of June 30,March 31, 2023 would result in an immaterial impact to Exelon's Consolidated Net Income.
Below is a summary of the interest rate hedge balances as of March 31, 2023 and December 31, 2022.
| | | | | | | | | | | | | | | | | |
| March 31, 2023 |
| Derivatives Designated
as Hedging Instruments | | Economic Hedges | | Total |
| | | | | |
| Other deferred debits (noncurrent assets) | $ | — | | | $ | 3 | | | $ | 3 | |
| Total derivative assets | — | | | 3 | | | 3 | |
| Mark-to-market derivative liabilities (current liabilities) | — | | | (1) | | | (1) | |
| Mark-to-market derivative liabilities (noncurrent liabilities) | (1) | | | — | | | (1) | |
| Total mark-to-market derivative liabilities | (1) | | | (1) | | | (2) | |
| Total mark-to-market derivative net assets | $ | (1) | | | $ | 2 | | | $ | 1 | |
| | | | | | | | | | | | | | | | | |
| December 31, 2022 |
| Derivatives Designated
as Hedging Instruments | | Economic Hedges | | Total |
| | | | | |
| Other deferred debits (noncurrent assets) | $ | 6 | | | $ | 5 | | | $ | 11 | |
| Total derivative assets | 6 | | | 5 | | | 11 | |
| Mark-to-market derivative liabilities (current liabilities) | — | | | (3) | | | (3) | |
| Mark-to-market derivative liabilities (noncurrent liabilities) | (4) | | | — | | | (4) | |
| Total mark-to-market derivative liabilities | (4) | | | (3) | | | (7) | |
| Total mark-to-market derivative net assets | $ | 2 | | | $ | 2 | | | $ | 4 | |
Cash Flow Hedges (Interest Rate Risk)
For derivative instruments that qualify and are designated as cash flow hedges, the changes in fair value each period are initially recorded in AOCI and reclassified into earnings when the underlying transaction affects earnings. The total notional of the swaps issued as of December 31, 2022 was $1.27 billion. In January 2023, Exelon Corporate entered into $115 million notional of 5-year maturity floating-to-fixed swaps and $115 million notional of 10-year maturity floating-to-fixed swaps, for a total of $230 million designated as cash flow hedges. In February 2023, Exelon terminated the previously issued floating-to-fixed swaps with a total notional of $1.5 billion upon issuance of $2.5 billion of debt. See Note 10 – Debt and Credit Agreements for additional information on the debt issuance. Prior to the termination, the AOCI derivative gain was $7 million (net of tax). The settlements resulted in a cash receipt of $10 million, which will be amortized into Interest expense in Exelon's Consolidated Statement of Operations and Comprehensive Income over the terms of the swaps. See Note 14 – Changes in Accumulated Other Comprehensive Income (Loss) for additional information.
In March 2023, Exelon Corporate entered into $65 million notional of 5-year maturity floating-to-fixed swaps and $65 million 10-year maturity floating-to-fixed swaps, for a total of $130 million designated as cash flow hedges. The related AOCI derivative gain for the three months ended as of March 31, 2023 was immaterial.
Economic Hedges (Interest Rate and Other Risk)
Exelon Corporate executes derivative instruments to mitigate exposure to fluctuations in interest rates but for which the fair value or cash flow hedge elections were not made. For derivatives intended to serve as economic hedges, fair value is recorded on the balance sheet and changes in fair value each period are recognized in earnings or as a regulatory asset or liability, if regulatory requirements are met, each period.
Exelon Corporate enters into floating-to-fixed interest rate cap swaps to manage a portion of interest rate exposure in connection with existing borrowings. In the fourth quarter of 2022, Exelon Corporate entered into $1
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 9 — Derivative Financial Instruments
billion notional of 18-month maturity floating-to-fixed interest rate cap swaps and $850 million notional of 6-month maturity floating-to-fixed interest rate cap swaps, for a total of $1.85 billion notional of floating-to-fixed interest rate cap swaps as of December 31, 2022. The 6-month maturity floating-to-fixed interest rate cap swaps of $850 million notional matured in March 2023. The total remaining notional of the swaps was $1 billion as of March 31, 2023.
Additionally, to manage potential fluctuations in Electric operating revenues related to ComEd's distribution formula rate, Exelon Corporate enters into 30-year constant maturity treasury interest rate (Corporate 30-year treasury) swaps. In the first quarter of 2023, Exelon Corporate entered into a total of $3.6 billion notional of calendar year 2023 Corporate 30-year treasury swaps. The total notional of the swaps issued was $4.1 billion and $500 million as of March 31, 2023 and December 31, 2021,2022, respectively.
For the three months ended March 31, 2023, Exelon Corporate recognized the following net pre-tax mark-to-market gains (losses) which are also recognized in Net fair value changes related to derivatives in Exelon's Consolidated Statements of Cash Flows. Exelon had no swaps for the three months ended March 31, 2022.
| | | | | | | | | | | | |
| | Gain (Loss) | | | | |
| Income Statement Location | | 2023 | | | | |
| Electric operating revenues | | $ | 1 | | | | | |
| Interest expense | | (1) | | | | | |
| Total | | $ | — | | | | | |
Credit Risk
The Registrants would be exposed to credit-related losses in the event of non-performance by counterparties on executed derivative instruments. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date. The Utility Registrants have contracts to procure electric and natural gas supply that provide suppliers with a certain amount of unsecured credit. If the exposure on the supply contract exceeds the amount of unsecured credit, the suppliers may be required to post collateral. The net credit exposure is mitigated primarily by the ability to recover procurement costs through customer rates. As of June 30, 2022, the amount of cash collateral held with external counterparties by Exelon, ComEd, BGE, PHI, Pepco, DPL, and ACE was $781 million, $133 million, $194 million, $452 million, $87 million, $224 million, and $141 million, respectively, which is recorded in Other current liabilities in Exelon's, ComEd's, BGE's, PHI's, Pepco's, DPL's, and ACE's Consolidated Balance Sheets. The amount of cash collateral received from external counterparties
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 9 — Derivative Financial Instruments
increased decreased as of June 30, 2022March 31, 2023 due to risingdecreasing energy prices. The amount of cash collateral for PECO was not materialimmaterial as of June 30, 2022. As ofMarch 31, 2023 and December 31, 2021,2022. The following table reflects the amounts for ComEd and DPL were $41 million and $43 million, respectively. The amounts for Exelon, PECO, BGE, PHI, Pepco, and ACE were not materialRegistrants' cash collateral held with external counterparties, which is recorded in Other current liabilities on their respective Consolidated Balance Sheets, as of March 31, 2023 and December 31, 2021.2022:
| | | | | | | | | | | | | | | | | | |
| | March 31, 2023 | | December 31, 2022 | | | | |
| Exelon | | $ | 81 | | | $ | 297 | | | | | |
| ComEd | | 73 | | | 77 | | | | | |
| BGE | | 1 | | | 23 | | | | | |
| PHI | | 8 | | | 197 | | | | | |
| Pepco | | 1 | | | 26 | | | | | |
| DPL | | 1 | | | 121 | | | | | |
| ACE | | 6 | | | 50 | | | | | |
The Utility Registrants’ electric supply procurement contracts do not contain provisions that would require them to post collateral. PECO’s, BGE’s, and DPL’s natural gas procurement contracts contain provisions that could require PECO, BGE, and DPL to post collateral in the form of cash or credit support, which vary by contract and counterparty, with thresholds contingent upon PECO’s, BGE's, and DPL’s credit rating. As of June 30, 2022,March 31, 2023, PECO, BGE, and DPL were not required to post collateral for any of these agreements. If PECO, BGE, or DPL lost their investment grade credit rating as of June 30, 2022,March 31, 2023, they could have been required to post collateral to their counterparties of $37$39 million, $75$73 million, and $15$14 million, respectively.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 10 — Debt and Credit Agreements
10. Debt and Credit Agreements (All Registrants)
Short-Term Borrowings
Exelon Corporate, ComEd, and BGE meet their short-term liquidity requirements primarily through the issuance of commercial paper. PECO meets their short-term liquidity requirements primarily through the issuance of commercial paper and borrowings from the Exelon intercompany money pool. Pepco, DPL, and ACE meet their short-term liquidity requirements primarily through the issuance of commercial paper and borrowings from the PHI intercompany money pool. PHI Corporate meets its short-term liquidity requirements primarily through the issuance of short-term notes and borrowings from the Exelon intercompany money pool. The Registrants may use their respective credit facilities for general corporate purposes, including meeting short-term funding requirements and the issuance of letters of credit.
Commercial Paper
The following table reflects the Registrants' commercial paper programs supported by the revolving credit agreements and bilateral credit agreements as of June 30, 2022March 31, 2023 and December 31, 2021. ComEd2022. As of March 31, 2023 and December 31, 2022, ACE had no commercial paper borrowings as of June 30, 2022 and December 31, 2021.borrowings:
| | | Outstanding Commercial
Paper as of | | Average Interest Rate on
Commercial Paper Borrowings as of | | Outstanding Commercial
Paper as of | | Average Interest Rate on
Commercial Paper Borrowings as of |
| Commercial Paper Issuer | Commercial Paper Issuer | June 30, 2022 | | December 31, 2021 | | June 30, 2022 | | December 31, 2021 | Commercial Paper Issuer | March 31, 2023 | | December 31, 2022 | | March 31, 2023 | | December 31, 2022 |
Exelon(a) | Exelon(a) | $ | 353 | | | $ | 599 | | | 1.86 | % | | 0.35 | % | Exelon(a) | $ | 807 | | | $ | 1,938 | | | 5.12 | % | | 4.77 | % |
| | ComEd | | ComEd | 409 | | | 427 | | | 5.09 | % | | 4.71 | % |
| PECO | PECO | 210 | | | — | | | 1.86 | % | | — | % | PECO | 145 | | | 239 | | | 5.04 | % | | 4.71 | % |
| BGE | BGE | — | | | 130 | | | — | % | | 0.37 | % | BGE | 243 | | | 409 | | | 5.24 | % | | 4.81 | % |
PHI(b) | PHI(b) | 43 | | | 469 | | | 1.85 | % | | 0.35 | % | PHI(b) | — | | | 414 | | | — | % | | 4.78 | % |
| | Pepco | Pepco | 43 | | | 175 | | | 1.85 | % | | 0.33 | % | Pepco | — | | | 299 | | | — | % | | 4.79 | % |
| DPL | DPL | — | | | 149 | | | — | % | | 0.36 | % | DPL | — | | | 115 | | | — | % | | 4.76 | % |
| ACE | — | | | 145 | | | — | % | | 0.35 | % | |
|
__________
(a)Exelon Corporate had $100$10 million of outstanding commercial paper borrowings at June 30, 2022 and no$449 million in outstanding commercial paper borrowings as of March 31, 2023 and December 31, 2021.2022, respectively.
(b)Represents the consolidated amounts of Pepco, DPL, and ACE.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 10 — Debt and Credit Agreements
Revolving Credit Agreements
On February 1, 2022, Exelon Corporate and the Utility Registrants'Registrants each entered intohave a new 5-year revolving credit facility that replaced its existing syndicated revolving credit facility. The following table reflects the credit agreements:
| | | | | | | | | | | | | | |
| Borrower | | Aggregate Bank Commitment | | Interest Rate |
| Exelon Corporate | | $ | 900 | | | SOFR plus 1.275 | % |
| ComEd | | 1,000 | | | SOFR plus 1.000 | % |
| PECO | | 600 | | | SOFR plus 0.900 | % |
| BGE | | 600 | | | SOFR plus 0.900 | % |
| Pepco | | 300 | | | SOFR plus 1.075 | % |
| DPL | | 300 | | | SOFR plus 1.000 | % |
| ACE | | 300 | | | SOFR plus 1.075 | % |
See Note 15 — DebtExelon Corporate and Credit Agreements of the 2021 Recast Form 10-K for additional informationUtility Registrants had no outstanding amounts on the Registrants'revolving credit facilities.facilities as of March 31, 2023.
Short-Term Loan Agreements
On March 23, 2017, Exelon Corporate entered into a term loan agreement for $500 million. The loan agreement was renewed on March 14, 2022Utility Registrants have credit facility agreements, arranged at minority and willcommunity banks, which are solely utilized to issue letters of credit. The new facility agreements have aggregate commitments of $40 million, $40 million, $15 million, $15 million, $15 million, and $15 million, at ComEd, PECO, BGE, Pepco, DPL, and ACE, respectively. These facilities expire on March 16,October 6, 2023. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to SOFR plus 0.65% and all indebtedness thereunder is unsecured. The loan agreement is reflected in Exelon's Consolidated Balance Sheets within Short-term borrowings.
On March 31, 2021, Exelon Corporate entered into a 364-day term loan agreement for $150 million with a variable interest rate of LIBOR plus 0.65% and an expiration date of March 30, 2022. Exelon Corporate repaid the term loan on March 30, 2022.
In connection with the separation, on January 24, 2022, Exelon Corporate entered into a 364-day term loan agreement for $1.15 billion. The loan agreement will expire on January 23, 2023. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to SOFR plus 0.75% with a 22.5 basis point increase which commenced on July 24, 2022. All indebtedness pursuant to the loan agreement is unsecured.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 10 — Debt and Credit Agreements
See Note 16 — Debt and Credit Agreements of the 2022 Form 10-K for additional information on the Registrants' credit facilities.
Short-Term Loan Agreements
On March 23, 2017, Exelon Corporate entered into a term loan agreement for $500 million. The loan agreement was renewed in the first quarter of 2023 and was bifurcated into two tranches of $300 million on March 14, 2023 and $200 million on March 24, 2023. The agreements will expire on March 14, 2024 and March 22, 2024, respectively. Pursuant to the loan agreements, loans made thereunder bear interest at a variable rate equal to SOFR plus 0.90% and all indebtedness thereunder is unsecured. The loan agreement is reflected in Exelon's Consolidated Balance Sheets within Short-term borrowings.
On October 4, 2022, ComEd entered into a 364-day term loan agreement for $150 million with a variable rate equal to SOFR plus 0.75% and an expiration date of October 3, 2023. The proceeds from this loan were used to repay outstanding commercial paper obligations. The balance of the loan was repaid on January 13, 2023 in conjunction with the $400 million and $575 million First Mortgage Bond agreements that were entered into on January 3, 2023. Refer to the Issuance of Long-Term Debt table below for further information.
Long-Term Debt
Issuance of Long-Term Debt
During the sixthree months ended June 30, 2022,March 31, 2023, the following long-term debt was issued:
| | Company | Company | | Type | | Interest Rate | | Maturity | | Amount | | Use of Proceeds | | Company | | Type | | Interest Rate | | Maturity | | Amount | | Use of Proceeds | |
| Exelon | Exelon | | SMBC Term Loan Agreement | | SOFR plus 0.65% | | July 21, 2023 | | $300 | | Fund a cash payment to Constellation and for general corporate purposes. | | Exelon | | Notes | | 5.15% | | March 15, 2028 | | $1,000 | | Repay existing indebtedness and for general corporate purposes. | |
| Exelon | Exelon | | U.S. Bank Term Loan Agreement | | SOFR plus 0.65% | | July 21, 2023 | | 300 | | Fund a cash payment to Constellation and for general corporate purposes. | | Exelon | | Notes | | 5.30% | | March 15, 2033 | | 850 | | Repay existing indebtedness and for general corporate purposes. | |
| Exelon | Exelon | | PNC Term Loan Agreement | | SOFR plus 0.65% | | July 24, 2023 | | 250 | | Fund a cash payment to Constellation and for general corporate purposes. | | Exelon | | Notes | | 5.60% | | March 15, 2053 | | 650 | | Repay existing indebtedness and for general corporate purposes. | |
| Exelon | | Notes(b) | | 2.75% | | March 15, 2027 | | 650 | | Repay existing indebtedness and for general corporate purposes. | | |
| Exelon | | Notes(b) | | 3.35% | | March 15, 2032 | | 650 | | Repay existing indebtedness and for general corporate purposes. | | |
| Exelon | | Notes(b) | | 4.10% | | March 15, 2052 | | 700 | | Repay existing indebtedness and for general corporate purposes. | | |
| ComEd | ComEd | | First Mortgage Bonds, Series 132 | | 3.15% | | March 15, 2032 | | 300 | | Repay outstanding commercial paper obligations and to fund other general corporate purposes. | | ComEd | | First Mortgage Bonds, Series 134 | | 4.90% | | February 1, 2033 | | 400 | | Repay outstanding commercial paper obligations and to fund other general corporate purposes. | |
| ComEd | ComEd | | First Mortgage Bonds, Series 133 | | 3.85% | | March 15, 2052 | | 450 | | Repay outstanding commercial paper obligations and to fund other general corporate purposes. | | ComEd | | First Mortgage Bonds Series 135 | | 5.30% | | February 1, 2053 | | 575 | | Repay outstanding commercial paper obligations and to fund other general corporate purposes. | |
| PECO | | First and Refunding Mortgage Bonds | | 4.60% | | May 15, 2052 | | 350 | | Refinance existing indebtedness and for general corporate purposes. | | |
| BGE | | Notes | | 4.55% | | June 1, 2052 | | 500 | | Repay outstanding commercial paper obligations, repay existing indebtedness, and for general corporate purposes. | | |
Pepco(a) | Pepco(a) | | First Mortgage Bonds | | 3.97% | | March 24, 2052 | | 400 | | Repay existing indebtedness and for general corporate purposes. | | Pepco(a) | | First Mortgage Bonds | | 5.30% | | March 15, 2033 | | 85 | | Repay existing indebtedness and for general corporate purposes. | |
| | Pepco | | Pepco | | First Mortgage Bonds | | 5.40% | | March 15, 2038 | | 40 | | Repay existing indebtedness and for general corporate purposes. | |
| Pepco | | Pepco | | First Mortgage Bonds | | 5.57% | | March 15, 2053 | | 125 | | Repay existing indebtedness and for general corporate purposes. | |
DPL(b) | | DPL(b) | | First Mortgage Bonds | | 5.30% | | March 15, 2033 | | 60 | | Repay existing indebtedness and for general corporate purposes. | |
| DPL | DPL | | First Mortgage Bonds | | 3.06% | | February 15, 2052 | | 125 | | Repay existing indebtedness and for general corporate purposes. | | DPL | | First Mortgage Bonds | | 5.57% | | March 15, 2053 | | 65 | | Repay existing indebtedness and for general corporate purposes. | |
| ACE | ACE | | First Mortgage Bonds | | 2.27% | | February 15, 2032 | | 25 | | Repay existing indebtedness and for general corporate purposes. | | ACE | | First Mortgage Bonds | | 5.57% | | March 15, 2053 | | 75 | | Repay existing indebtedness and for general corporate purposes. | |
| ACE | | First Mortgage Bonds | | 3.06% | | February 15, 2052 | | 150 | | Repay existing indebtedness and for general corporate purposes. | | |
|
__________
(a)On March 24, 2022,15, 2023, Pepco entered into a purchase agreement of First Mortgage Bonds of $225$100 million at 3.35%5.35% due on September 15, 2032.13, 2033. The closing date of the issuance is expected to occur in September 2022.2023.
(b)In connection with the issuance and sale of the Notes, ExelonOn March 15, 2023, DPL entered into a Registration Rights Agreement with the representativespurchase agreement of First Mortgage Bonds of $340 million, $75 million, and $110 million at 5.45%, 5.55% and 5.72% due on November 8, 2033, November 8, 2038, and November 8, 2053, respectively. The closing date of the initial purchasers of the Notes and other parties. Pursuantissuance is expected to the Registration Rights Agreement, Exelon will be obligated to file a registration statement with respect to an offer to exchange the Notes for substantially similar notes of Exelon that are registered under the Securities Act or,occur in certain circumstances, register the resale of the Notes. The registered exchange notes, if and when issued, will have terms identical in all material respects to the Notes, except that their issuance will have been registered under the Securities Act.November 2023.
Long-Term Debt to Affiliates
As of December 31, 2021, Exelon Corporate had $319 million recorded to intercompany notes receivable from Generation. See Note 15 — Debt and Credit Agreements of the 2021 Recast Form 10-K for additional information. In connection with the separation, on January 31, 2022, Exelon Corporate received cash from Generation of $258 million to settle the intercompany loan.
Debt Covenants
As of June 30, 2022,March 31, 2023, the Registrants are in compliance with debt covenants.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 11 — Fair Value of Financial Assets and Liabilities
11. Fair Value of Financial Assets and Liabilities (All Registrants)
Exelon measures and classifies fair value measurements in accordance with the hierarchy as defined by GAAP. The hierarchy prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:
•Level 1 -— quoted prices (unadjusted) in active markets for identical assets or liabilities that the Registrants have the ability to liquidate as of the reporting date.
•Level 2 -— inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.
•Level 3 -— unobservable inputs, such as internally developed pricing models or third-party valuations for the asset or liability due to little or no market activity for the asset or liability.
Fair Value of Financial Liabilities Recorded at Amortized Cost
The following tables present the carrying amounts and fair values of the Registrants’ short-term liabilities, long-term debt, and trust preferred securities (long-term debt to financing trusts or junior subordinated debentures) as of June 30, 2022March 31, 2023 and December 31, 2021.2022. The Registrants have no financial liabilities classified as Level 1.1 or measured using the NAV practical expedient.
The carrying amounts of the Registrants’ short-term liabilities as presented in their Consolidated Balance Sheets are representative of their fair value (Level 2) because of the short-term nature of these instruments.
| | | June 30, 2022 | | December 31, 2021 | | March 31, 2023 | | December 31, 2022 |
| | Carrying Amount | | Fair Value | | Carrying Amount | | Fair Value | | Carrying Amount | | Fair Value | | Carrying Amount | | Fair Value |
| | Level 2 | | Level 3 | | Total | | Level 2 | | Level 3 | | Total | | Level 2 | | Level 3 | | Total | | Level 2 | | Level 3 | | Total |
Long-Term Debt, including amounts due within one year(a) | Long-Term Debt, including amounts due within one year(a) | Long-Term Debt, including amounts due within one year(a) |
| Exelon | Exelon | | $ | 36,294 | | | $ | 30,960 | | | $ | 2,315 | | | $ | 33,275 | | | $ | 32,902 | | | $ | 34,897 | | | $ | 2,217 | | | $ | 37,114 | | Exelon | | $ | 40,088 | | | $ | 33,224 | | | $ | 2,870 | | | $ | 36,094 | | | $ | 37,074 | | | $ | 29,902 | | | $ | 2,327 | | | $ | 32,229 | |
| ComEd | ComEd | | 10,516 | | | 9,609 | | | — | | | 9,609 | | | 9,773 | | | 11,305 | | | — | | | 11,305 | | ComEd | | 11,480 | | | 10,236 | | | — | | | 10,236 | | | 10,518 | | | 9,006 | | | — | | | 9,006 | |
| PECO | PECO | | 4,192 | | | 3,772 | | | 50 | | | 3,822 | | | 4,197 | | | 4,740 | | | 50 | | | 4,790 | | PECO | | 4,613 | | | 3,946 | | | 50 | | | 3,996 | | | 4,612 | | | 3,864 | | | 50 | | | 3,914 | |
| BGE | BGE | | 4,456 | | | 4,096 | | | — | | | 4,096 | | | 3,961 | | | 4,406 | | | — | | | 4,406 | | BGE | | 4,208 | | | 3,685 | | | — | | | 3,685 | | | 4,207 | | | 3,613 | | | — | | | 3,613 | |
| PHI | PHI | | 8,027 | | | 4,853 | | | 2,265 | | | 7,118 | | | 7,547 | | | 5,970 | | | 2,167 | | | 8,137 | | PHI | | 8,553 | | | 4,632 | | | 2,820 | | | 7,452 | | | 8,120 | | | 4,507 | | | 2,277 | | | 6,784 | |
| Pepco | Pepco | | 3,642 | | | 2,465 | | | 1,104 | | | 3,569 | | | 3,445 | | | 3,201 | | | 975 | | | 4,176 | | Pepco | | 3,995 | | | 2,295 | | | 1,507 | | | 3,802 | | | 3,751 | | | 2,229 | | | 1,205 | | | 3,434 | |
| DPL | DPL | | 1,938 | | | 1,210 | | | 503 | | | 1,713 | | | 1,810 | | | 1,426 | | | 552 | | | 1,978 | | DPL | | 2,061 | | | 1,183 | | | 604 | | | 1,787 | | | 1,938 | | | 1,164 | | | 458 | | | 1,622 | |
| ACE | ACE | | 1,757 | | | 954 | | | 658 | | | 1,612 | | | 1,582 | | | 1,091 | | | 641 | | | 1,732 | | ACE | | 1,831 | | | 935 | | | 709 | | | 1,644 | | | 1,757 | | | 909 | | | 614 | | | 1,523 | |
| Long-Term Debt to Financing Trusts | Long-Term Debt to Financing Trusts | Long-Term Debt to Financing Trusts |
| Exelon | Exelon | | $ | 390 | | | $ | — | | | $ | 398 | | | $ | 398 | | | $ | 390 | | | $ | — | | | $ | 470 | | | $ | 470 | | Exelon | | $ | 390 | | | $ | — | | | $ | 392 | | | $ | 392 | | | $ | 390 | | | $ | — | | | $ | 384 | | | $ | 384 | |
| ComEd | ComEd | | 205 | | | — | | | 209 | | | 209 | | | 205 | | | — | | | 248 | | | 248 | | ComEd | | 205 | | | — | | | 207 | | | 207 | | | 205 | | | — | | | 204 | | | 204 | |
| PECO | PECO | | 184 | | | — | | | 189 | | | 189 | | | 184 | | | — | | | 222 | | | 222 | | PECO | | 184 | | | — | | | 185 | | | 185 | | | 184 | | | — | | | 180 | | | 180 | |
__________
(a)Includes unamortized debt issuance costs, unamortized debt discount and premium, net, purchase accounting fair value adjustments, and finance lease liabilities which are not fair valued. Refer to Note 15 -16 — Debt and Credit Agreements of the 2021 Recast2022 Form 10-K for unamortized debt issuance costs, unamortized debt discount and premium, net, and purchase accounting fair value adjustments and Note 10 -— Leases of the 2021 Recast2022 Form 10-K for finance lease liabilities.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 11 — Fair Value of Financial Assets and Liabilities
Recurring Fair Value Measurements
The following tables present assets and liabilities measured and recorded at fair value in the Registrants' Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of June 30, 2022March 31, 2023 and December 31, 2021:2022. The Registrants have no financial assets or liabilities measured using the NAV practical expedient:
Exelon
| | | As of June 30, 2022 | | As of December 31, 2021 | | As of March 31, 2023 | | As of December 31, 2022 |
| | Level 1 | | Level 2 | | Level 3 | | | Total | | Level 1 | | Level 2 | | Level 3 | | | Total | | Level 1 | | Level 2 | | Level 3 | | | Total | | Level 1 | | Level 2 | | Level 3 | | | Total |
| Assets | Assets | | | | | | | | | | | | | | | | | | Assets | | | | | | | | | | | | | | | | | |
Cash equivalents(a) | Cash equivalents(a) | $ | 1,319 | | | $ | — | | | $ | — | | | | $ | 1,319 | | | $ | 524 | | | $ | — | | | $ | — | | | | $ | 524 | | Cash equivalents(a) | $ | 523 | | | $ | — | | | $ | — | | | | $ | 523 | | | $ | 664 | | | $ | — | | | $ | — | | | | $ | 664 | |
| Rabbi trust investments | Rabbi trust investments | | | | | | Rabbi trust investments | | | | | |
| Cash equivalents | Cash equivalents | 63 | | | — | | | — | | | | 63 | | | 60 | | | — | | | — | | | | 60 | | Cash equivalents | 65 | | | — | | | — | | | | 65 | | | 62 | | | — | | | — | | | | 62 | |
| Mutual funds | Mutual funds | 52 | | | — | | | — | | | | 52 | | | 60 | | | — | | | — | | | | 60 | | Mutual funds | 49 | | | — | | | — | | | | 49 | | | 49 | | | — | | | — | | | | 49 | |
| Fixed income | Fixed income | — | | | 8 | | | — | | | | 8 | | | — | | | 10 | | | — | | | | 10 | | Fixed income | — | | | 7 | | | — | | | | 7 | | | — | | | 7 | | | — | | | | 7 | |
| Life insurance contracts | Life insurance contracts | — | | | 59 | | | 38 | | | | 97 | | | — | | | 61 | | | 37 | | | | 98 | | Life insurance contracts | — | | | 56 | | | 41 | | | | 97 | | | — | | | 58 | | | 40 | | | | 98 | |
| Rabbi trust investments subtotal | Rabbi trust investments subtotal | 115 | | | 67 | | | 38 | | | | 220 | | | 120 | | | 71 | | | 37 | | | | 228 | | Rabbi trust investments subtotal | 114 | | | 63 | | | 41 | | | | 218 | | | 111 | | | 65 | | | 40 | | | | 216 | |
| Mark-to-market derivative assets | — | | | — | | | 15 | | | | 15 | | | — | | | — | | | — | | | | — | | |
| | Interest rate derivative assets | | Interest rate derivative assets | | | | | |
| Derivatives designated as hedging instruments | | Derivatives designated as hedging instruments | — | | | — | | | — | | | | — | | | — | | | 6 | | | — | | | | 6 | |
| Economic hedges | | Economic hedges | — | | | 3 | | | — | | | | 3 | | | — | | | 5 | | | — | | | | 5 | |
| Interest rate derivative assets subtotal | | Interest rate derivative assets subtotal | — | | | 3 | | | — | | | | 3 | | | — | | | 11 | | | — | | | | 11 | |
| Total assets | Total assets | 1,434 | | | 67 | | | 53 | | | | 1,554 | | | 644 | | | 71 | | | 37 | | | | 752 | | Total assets | 637 | | | 66 | | | 41 | | | | 744 | | | 775 | | | 76 | | | 40 | | | | 891 | |
| Liabilities | Liabilities | | | | | | | | | | | | | | | | | | Liabilities | | | | | | | | | | | | | | | | | |
| Mark-to-market derivative liabilities | Mark-to-market derivative liabilities | — | | | — | | | (103) | | | | (103) | | | — | | | — | | | (219) | | | | (219) | | Mark-to-market derivative liabilities | — | | | — | | | (98) | | | | (98) | | | — | | | — | | | (84) | | | | (84) | |
| Interest rate derivative liabilities | | Interest rate derivative liabilities | | | | | |
| Derivatives designated as hedging instruments | | Derivatives designated as hedging instruments | — | | | (1) | | | — | | | | (1) | | | — | | | (4) | | | — | | | | (4) | |
| Economic hedges | | Economic hedges | — | | | (1) | | | — | | | | (1) | | | — | | | (3) | | | — | | | | (3) | |
| Interest rate derivative liabilities subtotal | | Interest rate derivative liabilities subtotal | — | | | (2) | | | — | | | | (2) | | | — | | | (7) | | | — | | | | (7) | |
| Deferred compensation obligation | Deferred compensation obligation | — | | | (73) | | | — | | | | (73) | | | — | | | (131) | | | — | | | | (131) | | Deferred compensation obligation | — | | | (75) | | | — | | | | (75) | | | — | | | (75) | | | — | | | | (75) | |
| Total liabilities | Total liabilities | — | | | (73) | | | (103) | | | | (176) | | | — | | | (131) | | | (219) | | | | (350) | | Total liabilities | — | | | (77) | | | (98) | | | | (175) | | | — | | | (82) | | | (84) | | | | (166) | |
| Total net assets (liabilities) | Total net assets (liabilities) | $ | 1,434 | | | $ | (6) | | | $ | (50) | | | | $ | 1,378 | | | $ | 644 | | | $ | (60) | | | $ | (182) | | | | $ | 402 | | Total net assets (liabilities) | $ | 637 | | | $ | (11) | | | $ | (57) | | | | $ | 569 | | | $ | 775 | | | $ | (6) | | | $ | (44) | | | | $ | 725 | |
__________
(a)Exelon excludes cash of $177$482 million and $464$345 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively, and restricted cash of $340$78 million and $49$81 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively, and includes long-term restricted cash of $59$180 million and $44$117 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively, which is reported in Other deferred debits and other assets in the Consolidated Balance Sheets.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 11 — Fair Value of Financial Assets and Liabilities
ComEd, PECO, and BGE
| | | ComEd | | PECO | | BGE | | ComEd | | PECO | | BGE |
| As of June 30, 2022 | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | |
| As of March 31, 2023 | | As of March 31, 2023 | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total |
| Assets | Assets | | | | | | | | | | | | | | | | | | | | | | | | Assets | | | | | | | | | | | | | | | | | | | | | | | |
Cash equivalents(a) | Cash equivalents(a) | $ | 409 | | | $ | — | | | $ | — | | | $ | 409 | | | $ | 11 | | | $ | — | | | $ | — | | | $ | 11 | | | $ | 318 | | | $ | — | | | $ | — | | | $ | 318 | | Cash equivalents(a) | $ | 454 | | | $ | — | | | $ | — | | | $ | 454 | | | $ | 11 | | | $ | — | | | $ | — | | | $ | 11 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 1 | |
| Rabbi trust investments | Rabbi trust investments | | Rabbi trust investments | |
| | Mutual funds | Mutual funds | — | | | — | | | — | | | — | | | 9 | | | — | | | — | | | 9 | | | 7 | | | — | | | — | | | 7 | | Mutual funds | — | | | — | | | — | | | — | | | 8 | | | — | | | — | | | 8 | | | 9 | | | — | | | — | | | 9 | |
| Life insurance contracts | Life insurance contracts | — | | | — | | | — | | | — | | | — | | | 16 | | | — | | | 16 | | | — | | | — | | | — | | | — | | Life insurance contracts | — | | | — | | | — | | | — | | | — | | | 15 | | | — | | | 15 | | | — | | | — | | | — | | | — | |
| Rabbi trust investments subtotal | Rabbi trust investments subtotal | — | | | — | | | — | | | — | | | 9 | | | 16 | | | — | | | 25 | | | 7 | | | — | | | — | | | 7 | | Rabbi trust investments subtotal | — | | | — | | | — | | | — | | | 8 | | | 15 | | | — | | | 23 | | | 9 | | | — | | | — | | | 9 | |
Mark-to-market derivative assets(b) | — | | | — | | | 15 | | | 15 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | |
| | Total assets | Total assets | 409 | | | — | | | 15 | | | 424 | | | 20 | | | 16 | | | — | | | 36 | | | 325 | | | — | | | — | | | 325 | | Total assets | 454 | | | — | | | — | | | 454 | | | 19 | | | 15 | | | — | | | 34 | | | 10 | | | — | | | — | | | 10 | |
| Liabilities | Liabilities | | | | | | | | | | | | | | | | | | | | | | | | Liabilities | | | | | | | | | | | | | | | | | | | | | | | |
Mark-to-market derivative liabilities(b) | Mark-to-market derivative liabilities(b) | — | | | — | | | (103) | | | (103) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Mark-to-market derivative liabilities(b) | — | | | — | | | (98) | | | (98) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Deferred compensation obligation | Deferred compensation obligation | — | | | (8) | | | — | | | (8) | | | — | | | (7) | | | — | | | (7) | | | — | | | (4) | | | — | | | (4) | | Deferred compensation obligation | — | | | (8) | | | — | | | (8) | | | — | | | (8) | | | — | | | (8) | | | — | | | (4) | | | — | | | (4) | |
| Total liabilities | Total liabilities | — | | | (8) | | | (103) | | | (111) | | | — | | | (7) | | | — | | | (7) | | | — | | | (4) | | | — | | | (4) | | Total liabilities | — | | | (8) | | | (98) | | | (106) | | | — | | | (8) | | | — | | | (8) | | | — | | | (4) | | | — | | | (4) | |
| Total net assets (liabilities) | Total net assets (liabilities) | $ | 409 | | | $ | (8) | | | $ | (88) | | | $ | 313 | | | $ | 20 | | | $ | 9 | | | $ | — | | | $ | 29 | | | $ | 325 | | | $ | (4) | | | $ | — | | | $ | 321 | | Total net assets (liabilities) | $ | 454 | | | $ | (8) | | | $ | (98) | | | $ | 348 | | | $ | 19 | | | $ | 7 | | | $ | — | | | $ | 26 | | | $ | 10 | | | $ | (4) | | | $ | — | | | $ | 6 | |
| | | ComEd | | PECO | | BGE | | ComEd | | PECO | | BGE |
| As of December 31, 2021 | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | |
| As of December 31, 2022 | | As of December 31, 2022 | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total |
| Assets | Assets | | | | | | | | | | | | | | | | | | | | | | | | Assets | | | | | | | | | | | | | | | | | | | | | | | |
Cash equivalents(a) | Cash equivalents(a) | $ | 237 | | | $ | — | | | $ | — | | | $ | 237 | | | $ | 9 | | | $ | — | | | $ | — | | | $ | 9 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Cash equivalents(a) | $ | 392 | | | $ | — | | | $ | — | | | $ | 392 | | | $ | 10 | | | $ | — | | | $ | — | | | $ | 10 | | | $ | 23 | | | $ | — | | | $ | — | | | $ | 23 | |
| Rabbi trust investments | Rabbi trust investments | | Rabbi trust investments | |
| Mutual funds | Mutual funds | — | | | — | | | — | | | — | | | 11 | | | — | | | — | | | 11 | | | 14 | | | — | | | — | | | 14 | | Mutual funds | — | | | — | | | — | | | — | | | 7 | | | — | | | — | | | 7 | | | 7 | | | — | | | — | | | 7 | |
| Life insurance contracts | Life insurance contracts | — | | | — | | | — | | | — | | | — | | | 16 | | | — | | | 16 | | | — | | | — | | | — | | | — | | Life insurance contracts | — | | | — | | | — | | | — | | | — | | | 15 | | | — | | | 15 | | | — | | | — | | | — | | | — | |
| Rabbi trust investments subtotal | Rabbi trust investments subtotal | — | | | — | | | — | | | — | | | 11 | | | 16 | | | — | | | 27 | | | 14 | | | — | | | — | | | 14 | | Rabbi trust investments subtotal | — | | | — | | | — | | | — | | | 7 | | | 15 | | | — | | | 22 | | | 7 | | | — | | | — | | | 7 | |
| Total assets | Total assets | 237 | | | — | | | — | | | 237 | | | 20 | | | 16 | | | — | | | 36 | | | 14 | | | — | | | — | | | 14 | | Total assets | 392 | | | — | | | — | | | 392 | | | 17 | | | 15 | | | — | | | 32 | | | 30 | | | — | | | — | | | 30 | |
| Liabilities | Liabilities | | | | | | | | | | | | | | | | | | | | | | | | Liabilities | | | | | | | | | | | | | | | | | | | | | | | |
Mark-to-market derivative liabilities(b) | Mark-to-market derivative liabilities(b) | — | | | — | | | (219) | | | (219) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Mark-to-market derivative liabilities(b) | — | | | — | | | (84) | | | (84) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Deferred compensation obligation | Deferred compensation obligation | — | | | (10) | | | — | | | (10) | | | — | | | (9) | | | — | | | (9) | | | — | | | (7) | | | — | | | (7) | | Deferred compensation obligation | — | | | (8) | | | — | | | (8) | | | — | | | (7) | | | — | | | (7) | | | — | | | (4) | | | — | | | (4) | |
| Total liabilities | Total liabilities | — | | | (10) | | | (219) | | | (229) | | | — | | | (9) | | | — | | | (9) | | | — | | | (7) | | | — | | | (7) | | Total liabilities | — | | | (8) | | | (84) | | | (92) | | | — | | | (7) | | | — | | | (7) | | | — | | | (4) | | | — | | | (4) | |
| Total net assets (liabilities) | Total net assets (liabilities) | $ | 237 | | | $ | (10) | | | $ | (219) | | | $ | 8 | | | $ | 20 | | | $ | 7 | | | $ | — | | | $ | 27 | | | $ | 14 | | | $ | (7) | | | $ | — | | | $ | 7 | | Total net assets (liabilities) | $ | 392 | | | $ | (8) | | | $ | (84) | | | $ | 300 | | | $ | 17 | | | $ | 8 | | | $ | — | | | $ | 25 | | | $ | 30 | | | $ | (4) | | | $ | — | | | $ | 26 | |
__________
(a)ComEd excludes cash of $21 million and $105 million as of June 30, 2022 and December 31, 2021, respectively, and restricted cash of $133$51 million and $42 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively, and restricted cash of $73 million and $77 million as of March 31, 2023 and December 31, 2022, respectively, and includes long-term restricted cash of $59$180 million and $43$117 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively, which is reported in Other deferred debits and other assets in the Consolidated Balance Sheets. PECO excludes cash of $21$25 million and $35$58 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively. BGE excludes cash of $36$19 million and $51$43 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively, and restricted cash of $205$1 million and $4$1 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively.
(b)The Level 3 balance consists of the current asset of $15 million and current and noncurrent liability of none$22 million and $103$76 million, respectively, as of June 30, 2022March 31, 2023 and none, $18$5 million and $201$79 million, respectively, as of December 31, 20212022 related to floating-to-fixed energy swap contracts with unaffiliated suppliers.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 11 — Fair Value of Financial Assets and Liabilities
PHI, Pepco, DPL, and ACE
| | | As of June 30, 2022 | | As of December 31, 2021 | | As of March 31, 2023 | | As of December 31, 2022 |
| PHI | PHI | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | PHI | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total |
| Assets | Assets | | | | | | | | | | | | | | | | Assets | | | | | | | | | | | | | | | |
Cash equivalents(a) | Cash equivalents(a) | $ | 557 | | | $ | — | | | $ | — | | | $ | 557 | | | $ | 110 | | | $ | — | | | $ | — | | | $ | 110 | | Cash equivalents(a) | $ | 35 | | | $ | — | | | $ | — | | | $ | 35 | | | $ | 205 | | | $ | — | | | $ | — | | | $ | 205 | |
| Rabbi trust investments | Rabbi trust investments | | Rabbi trust investments | |
| Cash equivalents | Cash equivalents | 60 | | | — | | | — | | | 60 | | | 59 | | | — | | | — | | | 59 | | Cash equivalents | 62 | | | — | | | — | | | 62 | | | 59 | | | — | | | — | | | 59 | |
| Mutual funds | Mutual funds | 11 | | | — | | | — | | | 11 | | | 14 | | | — | | | — | | | 14 | | Mutual funds | 10 | | | — | | | — | | | 10 | | | 11 | | | — | | | — | | | 11 | |
| Fixed income | Fixed income | — | | | 8 | | | — | | | 8 | | | — | | | 10 | | | — | | | 10 | | Fixed income | — | | | 7 | | | — | | | 7 | | | — | | | 7 | | | — | | | 7 | |
| Life insurance contracts | Life insurance contracts | — | | | 22 | | | 37 | | | 59 | | | — | | | 27 | | | 35 | | | 62 | | Life insurance contracts | — | | | 20 | | | 39 | | | 59 | | | — | | | 22 | | | 39 | | | 61 | |
| Rabbi trust investments subtotal | Rabbi trust investments subtotal | 71 | | | 30�� | | | 37 | | | 138 | | | 73 | | | 37 | | | 35 | | | 145 | | Rabbi trust investments subtotal | 72 | | | 27 | | | 39 | | | 138 | | | 70 | | | 29 | | | 39 | | | 138 | |
| Total assets | Total assets | 628 | | | 30 | | | 37 | | | 695 | | | 183 | | | 37 | | | 35 | | | 255 | | Total assets | 107 | | | 27 | | | 39 | | | 173 | | | 275 | | | 29 | | | 39 | | | 343 | |
| Liabilities | Liabilities | | | | | | | | | | | | | | | | Liabilities | | | | | | | | | | | | | | | |
| Deferred compensation obligation | Deferred compensation obligation | — | | | (14) | | | — | | | (14) | | | — | | | (18) | | | — | | | (18) | | Deferred compensation obligation | — | | | (13) | | | — | | | (13) | | | — | | | (14) | | | — | | | (14) | |
| | Total liabilities | Total liabilities | — | | | (14) | | | — | | | (14) | | | — | | | (18) | | | — | | | (18) | | Total liabilities | — | | | (13) | | | — | | | (13) | | | — | | | (14) | | | — | | | (14) | |
| Total net assets | Total net assets | $ | 628 | | | $ | 16 | | | $ | 37 | | | $ | 681 | | | $ | 183 | | | $ | 19 | | | $ | 35 | | | $ | 237 | | Total net assets | $ | 107 | | | $ | 14 | | | $ | 39 | | | $ | 160 | | | $ | 275 | | | $ | 15 | | | $ | 39 | | | $ | 329 | |
| | | Pepco | | DPL | | ACE | | Pepco | | DPL | | ACE |
| As of June 30, 2022 | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | |
| As of March 31, 2023 | | As of March 31, 2023 | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total |
| Assets | Assets | | | | | | | | | | | | | | | | | | | | | | | | Assets | | | | | | | | | | | | | | | | | | | | | | | |
Cash equivalents(a) | Cash equivalents(a) | $ | 115 | | | $ | — | | | $ | — | | | $ | 115 | | | $ | 223 | | | $ | — | | | $ | — | | | $ | 223 | | | $ | 218 | | | $ | — | | | $ | — | | | $ | 218 | | Cash equivalents(a) | $ | 26 | | | $ | — | | | $ | — | | | $ | 26 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 1 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 1 | |
| | Rabbi trust investments | Rabbi trust investments | | Rabbi trust investments | |
| Cash equivalents | Cash equivalents | 59 | | | — | | | — | | | 59 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Cash equivalents | 61 | | | — | | | — | | | 61 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | Life insurance contracts | Life insurance contracts | — | | | 22 | | | 37 | | | 59 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Life insurance contracts | — | | | 20 | | | 39 | | | 59 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Rabbi trust investments subtotal | Rabbi trust investments subtotal | 59 | | | 22 | | | 37 | | | 118 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Rabbi trust investments subtotal | 61 | | | 20 | | | 39 | | | 120 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total assets | Total assets | 174 | | | 22 | | | 37 | | | 233 | | | 223 | | | — | | | — | | | 223 | | | 218 | | | — | | | — | | | 218 | | Total assets | 87 | | | 20 | | | 39 | | | 146 | | | 1 | | | — | | | — | | | 1 | | | 1 | | | — | | | — | | | 1 | |
| Liabilities | Liabilities | | | | | | | | | | | | | | | | | | | | | | | | Liabilities | | | | | | | | | | | | | | | | | | | | | | | |
| Deferred compensation obligation | Deferred compensation obligation | — | | | (1) | | | — | | | (1) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Deferred compensation obligation | — | | | (1) | | | — | | | (1) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | Total liabilities | Total liabilities | — | | | (1) | | | — | | | (1) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Total liabilities | — | | | (1) | | | — | | | (1) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total net assets | Total net assets | $ | 174 | | | $ | 21 | | | $ | 37 | | | $ | 232 | | | $ | 223 | | | $ | — | | | $ | — | | | $ | 223 | | | $ | 218 | | | $ | — | | | $ | — | | | $ | 218 | | Total net assets | $ | 87 | | | $ | 19 | | | $ | 39 | | | $ | 145 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 1 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 1 | |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 11 — Fair Value of Financial Assets and Liabilities
| | | Pepco | | DPL | | ACE | | Pepco | | DPL | | ACE |
| As of December 31, 2021 | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | |
| As of December 31, 2022 | | As of December 31, 2022 | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total | | Level 1 | | Level 2 | | Level 3 | | Total |
| Assets | Assets | | | | | | | | | | | | | | | | | | | | | | | | Assets | | | | | | | | | | | | | | | | | | | | | | | |
Cash equivalents(a) | Cash equivalents(a) | $ | 31 | | | $ | — | | | $ | — | | | $ | 31 | | | $ | 43 | | | $ | — | | | $ | — | | | $ | 43 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Cash equivalents(a) | $ | 51 | | | $ | — | | | $ | — | | | $ | 51 | | | $ | 121 | | | $ | — | | | $ | — | | | $ | 121 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 1 | |
| Rabbi trust investments | Rabbi trust investments | | Rabbi trust investments | |
| Cash equivalents | Cash equivalents | 58 | | | — | | | — | | | 58 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Cash equivalents | 59 | | | — | | | — | | | 59 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | Life insurance contracts | Life insurance contracts | — | | | 27 | | | 35 | | | 62 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Life insurance contracts | — | | | 22 | | | 38 | | | 60 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Rabbi trust investments subtotal | Rabbi trust investments subtotal | 58 | | | 27 | | | 35 | | | 120 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Rabbi trust investments subtotal | 59 | | | 22 | | | 38 | | | 119 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total assets | Total assets | 89 | | | 27 | | | 35 | | | 151 | | | 43 | | | — | | | — | | | 43 | | | — | | | — | | | — | | | — | | Total assets | 110 | | | 22 | | | 38 | | | 170 | | | 121 | | | — | | | — | | | 121 | | | 1 | | | — | | | — | | | 1 | |
| Liabilities | Liabilities | | | | | | | | | | | | | | | | | | | | | | | | Liabilities | | | | | | | | | | | | | | | | | | | | | | | |
| Deferred compensation obligation | Deferred compensation obligation | — | | | (2) | | | — | | | (2) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Deferred compensation obligation | — | | | (1) | | | — | | | (1) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | Total liabilities | Total liabilities | — | | | (2) | | | — | | | (2) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Total liabilities | — | | | (1) | | | — | | | (1) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total net assets | Total net assets | $ | 89 | | | $ | 25 | | | $ | 35 | | | $ | 149 | | | $ | 43 | | | $ | — | | | $ | — | | | $ | 43 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Total net assets | $ | 110 | | | $ | 21 | | | $ | 38 | | | $ | 169 | | | $ | 121 | | | $ | — | | | $ | — | | | $ | 121 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | 1 | |
__________
(a)PHI excludes cash of $60$358 million and $100$165 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively, and restricted cash of $2$3 million and $3 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively. Pepco excludes cash of $14$124 million and $34$45 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively, and restricted cash of $2$3 million and $3 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively. DPL excludes cash of $26$142 million and $28$31 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively. ACE excludes cash of $15$70 million and $29$71 million as of June 30, 2022March 31, 2023 and December 31, 2021,2022, respectively.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 11 — Fair Value of Financial Assets and Liabilities
Reconciliation of Level 3 Assets and Liabilities
The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis during the three and six months ended June 30, 2022March 31, 2023 and 2021: | | | | | | | | | | | | | | | | | | | |
| | | | | | | |
| Exelon | | ComEd | | PHI and Pepco | | |
| Three Months Ended June 30, 2022 | Total | | Mark-to-Market
Derivatives | | Life Insurance Contracts | | |
| Balance as of April 1, 2022 | $ | (107) | | | $ | (144) | | | $ | 36 | | | |
| Total realized / unrealized gains | | | | | | | |
Included in net income(a) | 1 | | | — | | | 1 | | | |
| | | | | | | |
| | | | | | | |
| Included in regulatory assets/liabilities | 56 | | | 56 | | (b) | — | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| Balance at June 30, 2022 | $ | (50) | | | $ | (88) | | (c) | $ | 37 | | | |
| The amount of total gains included in income attributed to the change in unrealized gains related to assets and liabilities as of June 30, 2022 | $ | 1 | | | $ | — | | | $ | 1 | | | |
90 | | | | | | | | | | | | | | | | | | | |
| Exelon | | ComEd | | PHI and Pepco | | |
| Three Months Ended March 31, 2023 | Total | | Mark-to-Market
Derivatives | | Life Insurance Contracts | | |
| Balance as of December 31, 2022 | $ | (44) | | | $ | (84) | | | $ | 40 | | | |
| Total realized / unrealized gains | | | | | | | |
Included in net income(a) | 1 | | | — | | | 1 | | | |
| | | | | | | |
| | | | | | | |
| Included in regulatory assets/liabilities | (14) | | | (14) | | (b) | — | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| Balance as of March 31, 2023 | $ | (57) | | | $ | (98) | | (c) | $ | 41 | | | |
| The amount of total gains included in income attributed to the change in unrealized gains related to assets and liabilities as of March 31, 2023 | $ | 1 | | | $ | — | | | $ | 1 | | | |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 11 — Fair Value of Financial Assets and Liabilities
| | | | | | | | | | | | | | | | | | | |
| | | | | | | |
| Exelon | | ComEd | | PHI and Pepco | | |
| Three Months Ended June 30, 2021 | Total | | Mark-to-Market
Derivatives | | Life Insurance Contracts | | |
| Balance as of April 1, 2021 | $ | (260) | | | $ | (295) | | | $ | 35 | | | |
| Total realized / unrealized gains | | | | | | | |
Included in net income(a) | 1 | | | — | | | 1 | | | |
| | | | | | | |
| Included in regulatory assets | 30 | | | 30 | | (b) | — | | | |
| | | | | | | |
| Purchases, sales, and settlements | | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| Settlements | (2) | | | — | | | (2) | | | |
| | | | | | | |
| | | | | | | |
| Balance as of June 30, 2021 | $ | (231) | | | $ | (265) | | | $ | 34 | | | |
| The amount of total gains included in income attributed to the change in unrealized gains related to assets and liabilities as of June 30, 2021 | $ | 1 | | | $ | — | | | $ | 1 | | | |
| | | | | | | | | | | | | | | | | | | |
| Exelon | | ComEd | | PHI and Pepco | | |
| Six months ended June 30, 2022 | Total | | Mark-to-Market
Derivatives | | Life Insurance Contracts | | |
| Balance as of January 1, 2022 | $ | (182) | | | $ | (219) | | | $ | 35 | | | |
| Total realized / unrealized gains | | | | | | | |
Included in net income(a) | 2 | | | — | | | 2 | | | |
| | | | | | | |
| | | | | | | |
| Included in regulatory assets/liabilities | 131 | | | 131 | | (b) | — | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| Transfers out of Level 3 | (1) | | | — | | | — | | | |
| Balance as of June 30, 2022 | $ | (50) | | | $ | (88) | | (c) | $ | 37 | | | |
| The amount of total gains included in income attributed to the change in unrealized gains related to assets and liabilities as of June 30, 2022 | $ | 2 | | | $ | — | | | $ | 2 | | | |
| | | | | | | | | | | | | | | | | | | |
| Exelon | | ComEd | | PHI and Pepco | | |
| Six Months Ended June 30, 2021 | Total | | Mark-to-Market
Derivatives | | Life Insurance Contracts | | |
| Balance as of January 1, 2021 | $ | (267) | | | $ | (301) | | | $ | 34 | | | |
| Total realized / unrealized gains | | | | | | | |
Included in net income(a) | 2 | | | — | | | 2 | | | |
| | | | | | | |
| | | | | | | |
| Included in regulatory assets | 36 | | | 36 | | (b) | — | | | |
| | | | | | | |
| Purchases, sales, and settlements | | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| Settlements | (2) | | | — | | | (2) | | | |
| | | | | | | |
| | | | | | | |
| Balance as of June 30, 2021 | $ | (231) | | | $ | (265) | | | $ | 34 | | | |
| The amount of total gains included in income attributed to the change in unrealized gain related to assets and liabilities as of June 30, 2021 | $ | 2 | | | $ | — | | | $ | 2 | | | |
| | | | | | | | | | | | | | | | | | | |
| Exelon | | ComEd | | PHI and Pepco | | |
| Three Months Ended March 31, 2022 | Total | | Mark-to-Market
Derivatives | | Life Insurance Contracts | | |
| Balance as of December 31, 2021 | $ | (182) | | | $ | (219) | | | $ | 35 | | | |
| Total realized / unrealized gains | | | | | | | |
Included in net income(a) | 1 | | | — | | | 1 | | | |
| | | | | | | |
| | | | | | | |
| Included in regulatory assets | 75 | | | 75 | | (b) | — | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| Transfers out of Level 3 | (1) | | | — | | | — | | | |
| Balance as of March 31, 2022 | $ | (107) | | | $ | (144) | | | $ | 36 | | | |
| The amount of total gains included in income attributed to the change in unrealized gain related to assets and liabilities as of March 31, 2022 | $ | 1 | | | $ | — | | | $ | 1 | | | |
__________(a)Classified in Operating and maintenance expense in the Consolidated Statements of Operations and Comprehensive Income.
(b)Includes $59$25 million of increasesdecreases in fair value and a decreasean increase for realized gains due to settlements of $3$11 million recorded in purchasedPurchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended June 30, 2022.March 31, 2023. Includes $25$69 million of increases in fair value and an increase for realized losses due to settlements of $5$6 million recorded in purchasedPurchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended June 30, 2021. Includes $128 million of increases in fair value and an increase for realized losses due to settlements of $3 million recorded in purchase power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the six months ended June 30,March 31, 2022. Includes $23 million of increases in fair value and an increase for realized losses due to settlements of $13 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the six months ended June 30, 2021.
(c)The balance consists of $15 million of current assets anda current and noncurrent liability of none$22 million and $103$76 million, respectively, as of June 30, 2022.March 31, 2023.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 11 — Fair Value of Financial Assets and Liabilities
Valuation Techniques Used to Determine Fair Value
Exelon’s valuation techniques used to measure the fair value of the assets and liabilities shown in the tables below are in accordance with the policies discussed in Note 1617 — Fair Value of Financial Assets and Liabilities of the 2021 Recast2022 Form 10-K.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 11 — Fair Value of Financial Assets and Liabilities
Mark-to-Market Derivatives (Exelon and ComEd)
The table below discloses the significant unobservable inputs to the forward curve used to value mark-to-market derivatives.
| | Type of trade | Type of trade | | Fair Value as of June 30, 2022 | | Fair Value as of December 31, 2021 | | Valuation
Technique | | Unobservable
Input | | 2022 Range & Arithmetic Average | | 2021 Range & Arithmetic Average | Type of trade | | Fair Value as of March 31, 2023 | | Fair Value as of December 31, 2022 | | Valuation
Technique | | Unobservable
Input | | 2023 Range & Arithmetic Average | | 2022 Range & Arithmetic Average |
| Mark-to-market derivatives | Mark-to-market derivatives | | $ | (88) | | | $ | (219) | | | Discounted
Cash Flow | | Forward power price(a) | | $30.54 | - | $89.78 | $46.33 | | $28.65 | - | $47.10 | $33.96 | Mark-to-market derivatives | | $ | (98) | | | $ | (84) | | | Discounted
Cash Flow | | Forward power price(a) | | $22.49 | - | $83.26 | $47.69 | | $34.78 | - | $75.71 | $48.44 |
________
(a)An increase to the forward power price would increase the fair value.
12. Commitments and Contingencies (All Registrants)
The following is an update to the current status of commitments and contingencies set forth in Note 1718 — Commitments and Contingencies of the 2021 Recast2022 Form 10-K.
Commitments
PHI Merger Commitments (Exelon, PHI, Pepco, DPL, and ACE). Approval of the PHI Merger in Delaware, New Jersey, Maryland, and the District of Columbia was conditioned upon Exelon and PHI agreeing to certain commitments. The following amounts represent total commitment costs that have been recorded since the acquisition date and the total remaining obligations for Exelon, PHI, Pepco, DPL, and ACE as of June 30, 2022:March 31, 2023:
| | Description | Description | Exelon | | PHI | | Pepco | | DPL | | ACE | Description | Exelon | | PHI | | Pepco | | DPL | | ACE |
| Total commitments | Total commitments | $ | 513 | | | $ | 320 | | | $ | 120 | | | $ | 89 | | | $ | 111 | | Total commitments | $ | 513 | | | $ | 320 | | | $ | 120 | | | $ | 89 | | | $ | 111 | |
Remaining commitments(a) | Remaining commitments(a) | 61 | | | 53 | | | 44 | | | 6 | | | 3 | | Remaining commitments(a) | 48 | | | 42 | | | 37 | | | 3 | | | 2 | |
|
__________
(a)Remaining commitments extend through 2026 and include rate credits, energy efficiency programs and delivery system modernization.
In addition, DPL has committed to conducting three RFPs to procure up to a total of 120 MWs of wind RECs for the purpose of meeting Delaware's renewable portfolio standards. DPL has conducted two of the three wind REC RFPs. The first 40 MW wind REC tranche was conducted in 2017 and did not result in a purchase agreement. The second 40 MW wind REC tranche was conducted in 2018 and resulted in a proposed REC purchase agreement that was approved by the DEPSC in 2019. The RFP for the third and final 40 MW wind REC tranche is under way and bids will be evaluated in the third quarter of 2022, with a potential award in the fourth quarter of 2022.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 12 — Commitments and Contingencies
Commercial Commitments (All Registrants). The Registrants’ commercial commitments as of June 30, 2022,March 31, 2023, representing commitments potentially triggered by future events were as follows:
| | | Expiration within | | Expiration within |
| | Total | | 2022 | | 2023 | | 2024 | | 2025 | | 2026 | | 2027 and beyond | | Total | | 2023 | | 2024 | | 2025 | | 2026 | | 2027 | | 2028 and beyond |
| Exelon | Exelon | | | | | | | | | | | | | | Exelon | | | | | | | | | | | | | |
| Letters of credit | Letters of credit | $ | 17 | | | $ | 8 | | | $ | 9 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Letters of credit | $ | 19 | | | $ | 17 | | | $ | 2 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
Surety bonds(a) | Surety bonds(a) | 185 | | | 144 | | | 39 | | | 2 | | | — | | | — | | | — | | Surety bonds(a) | 205 | | | 190 | | | 15 | | | — | | | — | | | — | | | — | |
| Financing trust guarantees | Financing trust guarantees | 378 | | | — | | | — | | | — | | | — | | | — | | | 378 | | Financing trust guarantees | 378 | | | — | | | — | | | — | | | — | | | — | | | 378 | |
Guaranteed lease residual values(b) | Guaranteed lease residual values(b) | 30 | | | — | | | 2 | | | 6 | | | 6 | | | 5 | | | 11 | | Guaranteed lease residual values(b) | 29 | | | — | | | 5 | | | 6 | | | 5 | | | 4 | | | 9 | |
| Total commercial commitments | Total commercial commitments | $ | 610 | | | $ | 152 | | | $ | 50 | | | $ | 8 | | | $ | 6 | | | $ | 5 | | | $ | 389 | | Total commercial commitments | $ | 631 | | | $ | 207 | | | $ | 22 | | | $ | 6 | | | $ | 5 | | | $ | 4 | | | $ | 387 | |
| | ComEd | ComEd | | ComEd | |
| Letters of credit | Letters of credit | $ | 10 | | | $ | 4 | | | $ | 6 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Letters of credit | $ | 12 | | | $ | 10 | | | $ | 2 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
Surety bonds(a) | Surety bonds(a) | 16 | | | 9 | | | 5 | | | 2 | | | — | | | — | | | — | | Surety bonds(a) | 47 | | | 42 | | | 5 | | | — | | | — | | | — | | | — | |
| Financing trust guarantees | Financing trust guarantees | 200 | | | — | | | — | | | — | | | — | | | — | | | 200 | | Financing trust guarantees | 200 | | | — | | | — | | | — | | | — | | | — | | | 200 | |
| Total commercial commitments | Total commercial commitments | $ | 226 | | | $ | 13 | | | $ | 11 | | | $ | 2 | | | $ | — | | | $ | — | | | $ | 200 | | Total commercial commitments | $ | 259 | | | $ | 52 | | | $ | 7 | | | $ | — | | | $ | — | | | $ | — | | | $ | 200 | |
| | PECO | PECO | | PECO | |
| Letters of credit | Letters of credit | $ | 1 | | | $ | — | | | $ | 1 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Letters of credit | $ | 1 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
Surety bonds(a) | Surety bonds(a) | 3 | | | 1 | | | 2 | | | — | | | — | | | — | | | — | | Surety bonds(a) | 2 | | | 1 | | | 1 | | | — | | | — | | | — | | | — | |
| Financing trust guarantees | Financing trust guarantees | 178 | | | — | | | — | | | — | | | — | | | — | | | 178 | | Financing trust guarantees | 178 | | | — | | | — | | | — | | | — | | | — | | | 178 | |
| Total commercial commitments | Total commercial commitments | $ | 182 | | | $ | 1 | | | $ | 3 | | | $ | — | | | $ | — | | | $ | — | | | $ | 178 | | Total commercial commitments | $ | 181 | | | $ | 2 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | — | | | $ | 178 | |
| | BGE | BGE | | BGE | |
| Letters of credit | Letters of credit | $ | 2 | | | $ | 2 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Letters of credit | $ | 2 | | | $ | 2 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
Surety bonds(a) | Surety bonds(a) | 2 | | | 1 | | | 1 | | | — | | | — | | | — | | | — | | Surety bonds(a) | 3 | | | 2 | | | 1 | | | — | | | — | | | — | | | — | |
| Total commercial commitments | Total commercial commitments | $ | 4 | | | $ | 3 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Total commercial commitments | $ | 5 | | | $ | 4 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
| | PHI | PHI | | PHI | |
| Surety bonds(a) | Surety bonds(a) | $ | 95 | | | $ | 76 | | | $ | 19 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Surety bonds(a) | $ | 95 | | | $ | 90 | | | $ | 5 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
Guaranteed lease residual values(b) | Guaranteed lease residual values(b) | 30 | | | — | | | 2 | | | 6 | | | 6 | | | 5 | | | 11 | | Guaranteed lease residual values(b) | 29 | | | — | | | 5 | | | 6 | | | 5 | | | 4 | | | 9 | |
| Total commercial commitments | Total commercial commitments | $ | 125 | | | $ | 76 | | | $ | 21 | | | $ | 6 | | | $ | 6 | | | $ | 5 | | | $ | 11 | | Total commercial commitments | $ | 124 | | | $ | 90 | | | $ | 10 | | | $ | 6 | | | $ | 5 | | | $ | 4 | | | $ | 9 | |
| | Pepco | Pepco | | Pepco | |
| Surety bonds(a) | Surety bonds(a) | $ | 84 | | | $ | 71 | | | $ | 13 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Surety bonds(a) | $ | 84 | | | $ | 84 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
Guaranteed lease residual values(b) | Guaranteed lease residual values(b) | 10 | | | — | | | 1 | | | 2 | | | 2 | | | 2 | | | 3 | | Guaranteed lease residual values(b) | 10 | | | — | | | 2 | | | 2 | | | 2 | | | 1 | | | 3 | |
| Total commercial commitments | Total commercial commitments | $ | 94 | | | $ | 71 | | | $ | 14 | | | $ | 2 | | | $ | 2 | | | $ | 2 | | | $ | 3 | | Total commercial commitments | $ | 94 | | | $ | 84 | | | $ | 2 | | | $ | 2 | | | $ | 2 | | | $ | 1 | | | $ | 3 | |
| | DPL | DPL | | DPL | |
| Surety bonds(a) | Surety bonds(a) | $ | 7 | | | $ | 3 | | | $ | 4 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Surety bonds(a) | $ | 6 | | | $ | 2 | | | $ | 4 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
Guaranteed lease residual values(b) | Guaranteed lease residual values(b) | 13 | | | — | | | — | | | 3 | | | 3 | | | 2 | | | 5 | | Guaranteed lease residual values(b) | 12 | | | — | | | 2 | | | 2 | | | 2 | | | 2 | | | 4 | |
| Total commercial commitments | Total commercial commitments | $ | 20 | | | $ | 3 | | | $ | 4 | | | $ | 3 | | | $ | 3 | | | $ | 2 | | | $ | 5 | | Total commercial commitments | $ | 18 | | | $ | 2 | | | $ | 6 | | | $ | 2 | | | $ | 2 | | | $ | 2 | | | $ | 4 | |
| | ACE | ACE | | ACE | |
Surety bonds(a) | Surety bonds(a) | $ | 4 | | | $ | 2 | | | $ | 2 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | | Surety bonds(a) | $ | 5 | | | $ | 4 | | | $ | 1 | | | $ | — | | | $ | — | | | $ | — | | | $ | — | |
Guaranteed lease residual values(b) | Guaranteed lease residual values(b) | 7 | | | — | | | 1 | | | 1 | | | 1 | | | 1 | | | 3 | | Guaranteed lease residual values(b) | 7 | | | — | | | 1 | | | 2 | | | 1 | | | 1 | | | 2 | |
| Total commercial commitments | Total commercial commitments | $ | 11 | | | $ | 2 | | | $ | 3 | | | $ | 1 | | | $ | 1 | | | $ | 1 | | | $ | 3 | | Total commercial commitments | $ | 12 | | | $ | 4 | | | $ | 2 | | | $ | 2 | | | $ | 1 | | | $ | 1 | | | $ | 2 | |
|
__________
(a)Surety bonds — Guarantees issued related to contract and commercial agreements, excluding bid bonds.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 12 — Commitments and Contingencies
(b)Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The lease term associated with these assets ranges from 1 to 89 years. The maximum potential obligation at the end of the minimum lease term would be $74$65 million guaranteed by Exelon and PHI, of which $24$21 million, $31$27 million, and $19$17 million is guaranteed by Pepco, DPL, and ACE, respectively. Historically, payments under the guarantees have not been made and PHI believes the likelihood of payments being required under the guarantees is remote.
Environmental Remediation Matters
General (All Registrants). The Registrants’ operations have in the past, and may in the future, require substantial expenditures to comply with environmental laws. Additionally, under federal and state environmental laws, the Registrants are generally liable for the costs of remediating environmental contamination of property now or formerly owned by them and of property contaminated by hazardous substances generated by them. The Registrants own or lease a number of real estate parcels, including parcels on which their operations or the operations of others may have resulted in contamination by substances that are considered hazardous under environmental laws. In addition, the Registrants are currently involved in a number of proceedings relating to sites where hazardous substances have been deposited and may be subject to additional proceedings in the future. Unless otherwise disclosed, the Registrants cannot reasonably estimate whether they will incur significant liabilities for additional investigation and remediation costs at these or additional sites identified by the Registrants, environmental agencies or others, or whether such costs will be recoverable from third parties, including customers. Additional costs could have a material, unfavorable impact on the Registrants' financial statements.
MGP Sites (All Registrants). ComEd, PECO, BGE, and DPL have identified sites where former MGP or gas purification activities have or may have resulted in actual site contamination. For almost all of thesesome sites, there are additional PRPs that may share responsibility for the ultimate remediation of each location.
•ComEd has 2120 sites that are currently under some degree of active study and/or remediation. ComEd expects the majority of the remediation at these sites to continue through at least 2031.
•PECO has 6 sites that are currently under some degree of active study and/or remediation. PECO expects the majority of the remediation at these sites to continue through at least 2023.2024.
•BGE has 4 sites that currently require some level of remediation and/or ongoing activity. BGE expects the majority of the remediation at these sites to continue through at least 2023.2025.
•DPL has 1 site that is currently under study and the required cost at the site is not expected to be material.
The historical nature of the MGP and gas purification sites and the fact that many of the sites have been buried and built over, impacts the ability to determine a precise estimate of the ultimate costs prior to initial sampling and determination of the exact scope and method of remedial activity. Management determines its best estimate of remediation costs using all available information at the time of each study, including probabilistic and deterministic modeling for ComEd and PECO, and the remediation standards currently required by the applicable state environmental agency. Prior to completion of any significant clean up, each site remediation plan is approved by the appropriate state environmental agency.
ComEd, pursuant to an ICC order, and PECO, pursuant to a PAPUC order, are currently recovering environmental remediation costs of former MGP facility sites through customer rates. While BGE and DPL do not have riders for MGP clean-up costs, they have historically received recovery of actual clean-up costs in distribution rates.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 12 — Commitments and Contingencies
As of June 30, 2022March 31, 2023 and December 31, 2021,2022, the Registrants had accrued the following undiscounted amounts for environmental liabilities in Accrued expenses, Other current liabilities, and Other deferred credits and other liabilities in their respective Consolidated Balance Sheets:
| | | June 30, 2022 | | December 31, 2021 | | March 31, 2023 | | December 31, 2022 |
| | Total environmental
investigation and
remediation liabilities | | Portion of total related to
MGP investigation and
remediation | | Total environmental
investigation and
remediation liabilities | | Portion of total related to
MGP investigation and
remediation | | Total environmental
investigation and
remediation liabilities | | Portion of total related to
MGP investigation and
remediation | | Total environmental
investigation and
remediation liabilities | | Portion of total related to
MGP investigation and
remediation |
| Exelon | Exelon | $ | 347 | | | $ | 299 | | | $ | 352 | | | $ | 303 | | Exelon | $ | 421 | | | $ | 343 | | | $ | 409 | | | $ | 355 | |
| ComEd | ComEd | 274 | | | 273 | | | 279 | | | 279 | | ComEd | 313 | | | 312 | | | 325 | | | 324 | |
| PECO | PECO | 21 | | | 20 | | | 22 | | | 20 | | PECO | 25 | | | 23 | | | 25 | | | 23 | |
| BGE | BGE | 7 | | | 6 | | | 6 | | | 4 | | BGE | 9 | | | 8 | | | 9 | | | 8 | |
| PHI | PHI | 42 | | | — | | | 42 | | | — | | PHI | 70 | | | — | | | 46 | | | — | |
| Pepco | Pepco | 40 | | | — | | | 40 | | | — | | Pepco | 68 | | | — | | | 44 | | | — | |
| DPL | DPL | 1 | | | — | | | 1 | | | — | | DPL | 1 | | | — | | | 1 | | | — | |
| ACE | ACE | 1 | | | — | | | 1 | | | — | | ACE | 1 | | | — | | | 1 | | | — | |
Benning Road Site (Exelon, PHI, and Pepco). In September 2010, PHI received a letter from EPA identifying the Benning Road site as one of six land-based sites potentially contributing to contamination of the lower Anacostia River. A portion of the site, which is owned by Pepco, was formerly the location of an electric generating facility owned by Pepco subsidiary, Pepco Energy Services (PES), which became a part of Generation, following the 2016 merger between PHI and Exelon. This generating facility was deactivated in June 2012. The remaining portion of the site consists of a Pepco transmission and distribution service center that remains in operation. In December 2011, the U.S. District Court for the District of Columbia approved a Consent Decree entered into by Pepco and Pepco Energy Services (hereinafter "Pepco Entities") with the DOEE, which requires the Pepco Entities to conduct a Remedial Investigation and Feasibility Study (RI/FS) for the Benning Road site and an approximately 10 to 15-acre portion of the adjacent Anacostia River. The purpose of this RI/FS is to define the nature and extent of contamination from the Benning Road site and to evaluate remedial alternatives.
Pursuant to an internal agreement between the Pepco Entities, since 2013, Pepco has performed the work required by the Consent Decree and has been reimbursed for that work by an agreed upon allocation of costs between the Pepco Entities. In September 2019, the Pepco Entities issued a draft “final” RI report which DOEE approved on February 3, 2020. The Pepco Entities are developingcompleting a FS to evaluate possible remedial alternatives for submission to DOEE. The Court has established aIn October 2022, DOEE approved dividing the work to complete the landside portion of the FS from the waterside portion to expedite the overall schedule for completion of the FS, and approval by the DOEE, by September 16, 2022.project. After completion and approval of the landside FS, now scheduled for September 2023, DOEE will prepare a Proposed Plan for public comment and then issue a Record of Decision (ROD) identifying any further response actions determined to be necessary. necessary to address any landside issues. The DOEE will issue a separate ROD for the waterside FS when that work is completed which is now anticipated to be by March 31, 2024.
As part of the separation between Exelon and Constellation in February 2022, the internal agreement between the Pepco Entities for completion and payment for the remaining Consent Decree work was memorialized in a formal agreement for post-separation activities. A second post-separation assumption agreement between Exelon and Constellation transferred any of the potential remaining remediation liability, if any, of PES/Generation to a non-utility subsidiary of Exelon which going forward will be responsible for those liabilities. Exelon, PHI, and Pepco have determined that a loss associated with this matter is probable and have accrued an estimated liability, which is included in the table above.
Anacostia River Tidal Reach (Exelon, PHI, and Pepco). Contemporaneous with the Benning Road site RI/FS being performed by the Pepco Entities, DOEE and National Park Service (NPS)NPS have been conducting a separate RI/FS focused on the entire tidal reach of the Anacostia River extending from just north of the Maryland-District of Columbia boundary line to the confluence of the Anacostia and Potomac Rivers. The river-wide RI incorporated the results of the river sampling performed by the Pepco Entities as part of the Benning RI/FS, as well as similar sampling efforts conducted by owners of other sites adjacent to this segment of the river and supplemental river sampling conducted by DOEE’s contractor.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 12 — Commitments and Contingencies
On September 30, 2020, DOEE released its Interim ROD. The Interim ROD reflects an adaptive management approach which will require several identified “hot spots” in the river to be addressed first while continuing to conduct studies and to monitor the river to evaluate improvements and determine potential future remediation plans. The adaptive management process chosen by DOEE is less intrusive, provides more long-term
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 12 — Commitments and Contingencies
environmental certainty, is less costly, and allows for site specific remediation plans already underway, including the plan for the Benning Road site to proceed to conclusion.
On July 15, 2022, Pepco received a letter from the District of Columbia's Office of the Attorney General (District)(D.C. OAG) on behalf of DOEE conveying a settlement offer to resolve all PRPs' liability to the District.District of Columbia (District) for their past costs and their anticipated future costs to complete the work for the Interim ROD. Pepco responded on July 27, 2022 to enter into settlement discussions. Since that time Exelon and the other PRPs at the site have exchanged letters with the D.C. OAG exploring potential settlement options. Those discussions are ongoing. Exelon, PHI, and Pepco have determined that it is probable that costs for remediation will be incurred and have accrued a liability for management's best estimate of its share of the costs. Pepco concluded that incremental exposure remains reasonably possible, but management cannot reasonably estimate a range of loss beyond the amounts recorded, which are included in the table above.
In addition to the activities associated with the remedial process outlined above, CERCLA separately requires federal and state (here including Washington, D.C.) Natural Resource Trustees (federal or state agencies designated by the President or the relevant state, respectively, or Indian tribes) to conduct an assessment of any damages to natural resources within their jurisdiction as a result of the contamination that is being remediated. The Trustees can seek compensation from responsible parties for such damages, including restoration costs. During the second quarter of 2018, Pepco became aware that the Trustees are in the beginning stages of a Natural Resources Damages (NRD)NRD assessment, a process that often takes many years beyond the remedial decision to complete. Pepco has entered into negotiations with the Trustees to evaluate possible incorporation of NRD assessment and restoration as part of its remedial activities associated with the Benning site to accelerate the NRD benefits for that portion of the Anacostia River Sediment Project ("ARSP")(ARSP) assessment. Pepco has concluded that a loss associated with the eventual NRD assessment is reasonably possible. Due to the very early stage of the assessment process, Pepco cannot reasonably estimate the final range of loss potentially resulting from this process.
As noted in the Benning Road Site disclosure above, as part of the separation of Exelon and Constellation in February 2022, an assumption agreement was executed transferring any potential future remediation liabilities associated with the Benning Site remediation to a non-utility subsidiary of Exelon. Similarly, any potential future liability associated with the ARSP was also assumed by this entity.
Buzzard Point Site (Exelon, PHI, and Pepco). On December 8, 2022, Pepco received a letter from the D.C. OAG, alleging wholly past violations of the District's stormwater discharge and waste disposal requirements related to operations at the Buzzard Point facility, a 9-acre parcel of waterfront property in Washington, D.C. occupied by an active substation and former steam plant building. The letter also alleged wholly past violations by Pepco of stormwater discharge requirements related to its district-wide system of underground vaults. The D.C. OAG invited Pepco to resolve the threatened enforcement action through a court-approved consent decree, and Pepco is engaged in discussions with the D.C. OAG regarding a potential resolution. Exelon, PHI, and Pepco have determined that a loss associated with this matter is probable and have accrued an estimated liability. Pepco concluded that incremental exposure is reasonably possible, but the range of loss cannot be reasonably estimated beyond the amounts included in the table above.
Litigation and Regulatory Matters
Deferred Prosecution Agreement (DPA)DPA and Related Matters (Exelon and ComEd). Exelon and ComEd received a grand jury subpoena in the second quarter of 2019 from the U.S. Attorney’s Office for the Northern District of Illinois (USAO) requiring production of information concerning their lobbying activities in the State of Illinois. On October 4, 2019, Exelon and ComEd received a second grand jury subpoena from the USAO requiring production of records of any communications with certain individuals and entities. On October 22, 2019, the SEC notified Exelon and ComEd that it had also opened an investigation into their lobbying activities. On July 17, 2020, ComEd entered into a DPA with the USAO to resolve the USAO investigation. Under the DPA, the USAO filed a single charge alleging that ComEd improperly gave and offered to give jobs, vendor subcontracts, and payments associated with those jobs and subcontracts for the benefit of the former Speaker of the Illinois House of Representatives and the Speaker’s associates, with the intent to influence the Speaker’s action regarding legislation affecting ComEd’s
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 12 — Commitments and Contingencies
interests. The DPA provides that the USAO will defer any prosecution of such charge and any other criminal or civil case against ComEd in connection with the matters identified therein for a three-year period subject to certain obligations of ComEd, including payment to the U.S. Treasury of $200 million, which was paid in November 2020. Exelon was not made a party to the DPA, and therefore the investigation by the USAO into Exelon’s activities ended with no charges being brought against Exelon. The SEC’s investigation remains ongoing and Exelon and ComEd have cooperated fully and intend to continue to cooperate fully with the SEC. Exelon and ComEd cannot predict the outcome of the SEC investigation. No loss contingency has been reflected in Exelon's and ComEd's consolidated financial statements with respect to the SEC investigation, as this contingency is neither probable nor reasonably estimable at this time.
Subsequent to Exelon announcing the receipt of the subpoenas, various lawsuits were filed, and various demand letters were received related to the subject of the subpoenas, the conduct described in the DPA and the SEC's investigation, including:
•Four putative class action lawsuits against ComEd and Exelon were filed in federal court on behalf of ComEd customers in the third quarter of 2020 alleging, among other things, civil violations of federal racketeering laws. In addition, the Citizens Utility Board (CUB) filed a motion to intervene in these cases on October 22, 2020 which was granted on December 23, 2020. On December 2, 2020, the court
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 12 — Commitments and Contingencies
appointed interim lead plaintiffs in the federal cases which consisted of counsel for three of the four federal cases. These plaintiffs filed a consolidated complaint on January 5, 2021. CUB also filed its own complaint against ComEd only on the same day. The remaining federal case, Potter, et al. v. Exelon et al, differed from the other lawsuits as it named additional individual defendants not named in the consolidated complaint. However, the Potter plaintiffs voluntarily dismissed their complaint without prejudice on April 5, 2021. ComEd and Exelon moved to dismiss the consolidated class action complaint and CUB’s complaint on February 4, 2021 and briefing was completed on March 22, 2021. On March 25, 2021, the parties agreed, along with state court plaintiffs, discussed below, to jointly engage in mediation. The parties participated in a one-day mediation on June 7, 2021 but no settlement was reached. On September 9, 2021, the federal court granted Exelon’s and ComEd’s motion to dismiss and dismissed the plaintiffs’ and CUB’s federal law claim with prejudice. The federal court also dismissed the related state law claims made by the federal plaintiffs and CUB on jurisdictional grounds. Plaintiffs appealed dismissal of the federal law claim to the Seventh Circuit Court of Appeals. Plaintiffs and CUB also refiled their state law claims in state court and moved to consolidate them with the already pending consumer state court class action, discussed below. Plaintiffs' opening appeal brief inOn August 22, 2022, the Seventh Circuit was filed on January 14, 2022. Exelonaffirmed the dismissal of the consolidated federal cases in their entirety. The time to further appeal has passed and ComEd filed their response brief on March 7, 2022, and plaintiffs filed their reply brief on April 6, 2022. Oral argument was held on May 17, 2022.the Seventh Circuit’s decision is final.
•Three putative class action lawsuits against ComEd and Exelon were filed in Illinois state court in the third quarter of 2020 seeking restitution and compensatory damages on behalf of ComEd customers. The cases were consolidated into a single action in October of 2020. In November 2020, CUB filed a motion to intervene in the cases pursuant to an Illinois statute allowing CUB to intervene as a party or otherwise participate on behalf of utility consumers in any proceeding which affects the interest of utility consumers. On November 23, 2020, the court allowed CUB’s intervention, but denied CUB's request to stay these cases. Plaintiffs subsequently filed a consolidated complaint, and ComEd and Exelon filed a motion to dismiss on jurisdictional and substantive grounds on January 11, 2021. Briefing on that motion was completed on March 2, 2021. The parties agreed, on March 25, 2021, along with the federal court plaintiffs discussed above, to jointly engage in mediation. The parties participated in a one-day mediation on June 7, 2021 but no settlement was reached. On December 23, 2021, the state court granted ComEd and Exelon's motion to dismiss with prejudice. On December 30, 2021, plaintiffs filed a motion to reconsider that dismissal and for permission to amend their complaint. The court denied the plaintiffs' motion on January 21, 2022. Plaintiffs have appealed the court's ruling dismissing their complaint to the First District Court of Appeals. On February 15, 2022, Exelon and ComEd moved to dismiss the federal plaintiffs' refiled state law claims, seeking dismissal on the same legal grounds asserted in their motion to dismiss the original state court plaintiffs' complaint. The court granted dismissal of the refiled state claims on February 16, 2022. The original federal plaintiffs appealed that dismissal on February 18, 2022. The two state appeals were consolidated on March 21, 2022. Plaintiffs' openingThe appellate briefsbriefing is complete and the parties are currently due August 5, 2022.awaiting oral argument and/or a decision.
•On November 3, 2022, a plaintiff filed a putative class action complaint in Lake County, Illinois Circuit Court against ComEd and Exelon for unjust enrichment and deceptive business practices in connection with the conduct giving rise to the DPA. Plaintiff seeks an accounting and disgorgement of any benefits ComEd allegedly obtained from said conduct. Plaintiff served initial discovery requests on ComEd in December 2022, to which ComEd has responded. ComEd and Exelon filed a motion to dismiss the Complaint on February 3, 2023. The parties fully briefed the motion, and on April 21, 2023, the court heard oral argument on the motion. The court expects to issue its ruling on the motion to dismiss on or before June 9, 2023.
•A putative class action lawsuit against Exelon and certain officers of Exelon and ComEd was filed in federal court in December 2019 alleging misrepresentations and omissions in Exelon’s SEC filings
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 12 — Commitments and Contingencies
related to ComEd’s lobbying activities and the related investigations. The complaint was amended on September 16, 2020, to dismiss two of the original defendants and add other defendants, including ComEd. Defendants filed a motion to dismiss in November 2020. The court denied the motion in April 2021. On May 26, 2021, defendants moved the court to certify its order denying the motion to dismiss for interlocutory appeal. Briefing on the motion was completed in June 2021. That motion was denied on January 28, 2022. In May 2021, the parties each filed respective initial discovery disclosures. On June 9, 2021, defendants filed their answer and affirmative defenses to the complaint and the parties engaged thereafter in discovery. On September 9, 2021, the U.S. government moved to intervene in the lawsuit and stay discovery until the parties entered into an amendment to their protective order that would prohibit the parties from requesting discovery into certain matters, including communications with the U.S. government. The court ordered said amendment to the protective order on November 15, 2021 and discovery resumed. On February 10, 2022, theThe court granted an extension of the amendment tofurther amended the protective order at the U.S. government's request. The court granted a further extension of the amendment to the protective order and narrowed its scope, at the U.S. government's request, on May 14, 2022. On July 14, 2022, the court further extended the protective order amendment to September 30,October 17, 2022 and reset theextended it until May 15, 2023. The next court status is set for August 15, 2022.June 27, 2023.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars$173 million. Management anticipates that such loss would be fully covered by insurance. The probable loss and the expected insurance recovery are reflected in millions, except per share data, unless otherwise noted)
Note 12 — CommitmentsExelon's Consolidated Balance Sheets within Accrued expenses and Contingencies
Other accounts receivable, respectively.•Several shareholders have sent letters to the Exelon Board of Directors fromsince 2020 through May 2022 demanding, among other things, that the Exelon Board of Directors investigate and address alleged breaches of fiduciary duties and other alleged violations by Exelon and ComEd officers and directors related to the conduct described in the DPA. In the first quarter of 2021, the Exelon Board of Directors appointed a Special Litigation Committee (SLC) consisting of disinterested and independent parties to investigate and address these shareholders’ allegations and make recommendations to the Exelon Board of Directors based on the outcome of the SLC’s investigation. In July 2021, one of the demand letter shareholders filed a derivative action against current and former Exelon and ComEd officers and directors, and against Exelon, as nominal defendant, asserting the same claims made in its demand letter. On October 12, 2021, the parties to the derivative action filed an agreed motion to stay that litigation for 120 days in order to allow the SLC to continue its investigation, which the court granted. The stay has been extended several times. On February 3, 2022,March 27, 2023, the court grantedissued an extension oforder further extending the stay for another 120 days and directed the parties to fileuntil June 9, 2023, with a status report on Junedue by May 31, 2023. The parties participated in a mediation in February 2023 and efforts to resolve the matter remain ongoing. On April 26 and May 1, 2022. On June 1, 2022, the2023, two additional demand letter shareholders each filed a separate derivative lawsuit against current and former Exelon and ComEd officers and directors, and certain third parties, requested a further extension of the stay until September 14, 2022, which the court granted.and against Exelon as nominal defendant, asserting claims similar to those made in their respective demand letters.
•Two separate shareholderSeveral shareholders have sent requests seeking review of certain Exelon books and records were received insince August 2021 and January 2022.2021. Exelon has responded to both requests and both shareholders have since sent formal shareholder demands to the Exelon Board,each request.
Except as discussed above.
Nonoted above, no loss contingencies have been reflectedreflected in Exelon’sExelon's and ComEd’sComEd's consolidated financial statements with respect to these matters, as such contingencies are neither probable nor reasonably estimable at this time.
TheIn August 2022, the ICC continues to conduct anconcluded its investigation initiated on August 12, 2021 into rate impacts of conduct admitted in the DPA, initiated on August 12, 2021. On December 16, 2021, ComEd filed direct testimony addressingincluding the costs recovered from customers related to the DPA and Exelon's funding of the fine paid by ComEd. InOn August 17, 2022, the ICC issued its final order accepting ComEd's voluntary customer refund offer of approximately $38 million (of which about $31 million is ICC jurisdictional; the remaining balance is FERC jurisdictional) that testimony, ComEd proposed to voluntarilyresolves the question of whether customer funds were used for DPA related activities. The customer refund to customers compensation costsincludes the cost of the former officers charged with wrongdoing in connection with events described in the DPA for the period during which those events occurred as well as costs, previously proposed to be returned, of individuals and entities specificallyevery individual or entity that was either (i) identified in the DPA as well as individuals and entities who were referred toor (ii) identified by ComEd as partan associate of the conduct describedformer Speaker of the Illinois House of Representatives in the DPA and who failed, during their tenure at ComEd, to perform work to management expectations.ICC proceeding. The testimony supports the calculation of the refund amount and proposes a refund mechanism (one-time bill credit in April 2023) and also addresses other topics outlinedICC rejected an argument by statute and the ICC orders initiating the investigation. On April 14, 2022, in response to rebuttal testimony from ICC staff and the Illinois Attorney General, City of Chicago, and CUB ComEd filed surrebuttal testimony, in which ComEd proposedthat a costly permanent adjustment also needed to increase its voluntary customer refundbe made to $38 million, including ICC and FERC jurisdictional amounts and estimated interest, to resolve the issueComEd's ratemaking capital structure on account of Exelon having funded ComEd's payment of the potential expenditureDPA fine with an equity infusion. On October 6, the ICC denied the application for rehearing filed by the Illinois Attorney General, City of customer moniesChicago, and CUB that specifically focused on activities identified intheir capital structure argument. The window to file an appeal on the ICC final order has expired and the ICC’s DPA in this matter.investigation is now closed. An accrual for the amount of the voluntary customer refund has been recorded in Other currentRegulatory liabilities and Other deferred credits and other liabilitiesRegulatory assets in Exelon’s and ComEd’s Consolidated Balance Sheets as of June 30, 2022.March 31, 2023. The voluntaryICC jurisdictional refund is being made to customers during the April 2023 billing cycle, as required by the ICC. The FERC jurisdictional refund will be made as part of the next transmission formula rate
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 12 — Commitments and Contingencies
update proceeding in 2023. The customer refund will not be recovered in rates or charged to customers and ComEd will not seek or accept reimbursement or indemnification from any source other than Exelon. The evidentiary hearing on the remaining contested issue was held on April 28, 2022. On June 13, 2022, the ICC Administrate Law Judge issued a proposed order, which accepts ComEd's voluntary customer refund of $38 million and rejects alternative proposals for other larger adjustments to rates. A final order is expected by September 9, 2022.
Savings Plan Claim (Exelon).On December 6, 2021, seven current and former employees filed a putative ERISA class action suit in U.S. District Court for the Northern District of Illinois against Exelon, its Board of Directors, the former Board Investment Oversight Committee, the Corporate Investment Committee, individual defendants, and other unnamed fiduciaries of the Exelon Corporation Employee Savings Plan (Plan). The complaint alleges that the defendants violated their fiduciary duties under the Plan by including certain investment options that allegedly were more expensive than and underperformed similar passively-managed or other funds available in the marketplace and permitting a third-party administrative service provider/recordkeeper and an investment adviser to charge excessive fees for the services provided. The plaintiffs seek declaratory, equitable and monetary relief on behalf of the Plan and participants. On February 16, 2022, the court granted the parties' stipulated dismissal of the individual named defendants without prejudice. The remaining defendants filed a motion to dismiss the complaint on February 25, 2022. The plaintiffs filed their response brief on March 28, 2022 and the defendants filed their reply on April 11, 2022. On March 4, 2022, the Chamber of Commerce filed a brief of amicus curiae in support of the defendants' motion to dismiss. On September 22, 2022, the court granted Exelon’s motion to dismiss without prejudice. The court granted plaintiffs leave until October 31, 2022 to file an amended complaint, which was later extended to November 30, 2022. Plaintiffs filed their amended complaint on November 30, 2022. Defendants filed their motion to dismiss the amended complaint on January 20, 2023. Briefing on the motion to dismiss is now complete and the parties await a ruling. No loss contingencies have been reflected in Exelon’s consolidated financial statements with respect to this matter, as such contingencies are neither probable nor reasonably estimable at this time.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 12 — Commitments and Contingencies
General (All Registrants). The Registrants are involved in various other litigation matters that are being defended and handled in the ordinary course of business. The Registrants are also from time to time subject to audits and investigations by the FERC and other regulators. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of loss is estimable, often involves a series of complex judgments about future events. The Registrants maintain accruals for such losses that are probable of being incurred and subject to reasonable estimation. Management is sometimes unable to estimate an amount or range of reasonably possible loss, particularly where (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution of such matters, including a possible eventual loss.
13. Shareholders' Equity (Exelon)
At-the-Market (ATM) Program
On August 4, 2022, Exelon executed an equity distribution agreement (“Equity Distribution Agreement”), with certain sales agents and forward sellers and certain forward purchasers, establishing an ATM equity distribution program under which it may offer and sell shares of its Common Stock, having an aggregate gross sales price of up to $1.0 billion. Exelon has no obligation to offer or sell any shares of Common Stock under the Equity Distribution Agreement and may, at any time, suspend or terminate offers and sales under the Equity Distribution Agreement. As of March 31, 2023, Exelon has not issued any shares of Common Stock under the ATM program and has not entered into any forward sale agreements.
14. Changes in Accumulated Other Comprehensive Income (Loss) (Exelon)
The following tables present changes in Exelon's AOCI, net of tax, by component:
| | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended June 30, 2022 | Cash Flow Hedges | | Pension and Non-Pension Postretirement Benefit Plan Items(a) | | Foreign
Currency
Items | | | | Total |
| Balance at March 31, 2022 | $ | — | | | $ | (713) | | | $ | — | | | | | $ | (713) | |
| OCI before reclassifications | — | | | 2 | | | — | | | | | 2 | |
| Amounts reclassified from AOCI | — | | | 10 | | | — | | | | | 10 | |
| Net current-period OCI | — | | | 12 | | | — | | | | | 12 | |
| Balance at June 30, 2022 | $ | — | | | $ | (701) | | | $ | — | | | | | $ | (701) | |
| | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended June 30, 2021 | Cash Flow Hedges | | Pension and Non-Pension Postretirement Benefit Plan Items(a) | | Foreign
Currency
Items | | | | Total |
| Balance at March 31, 2021 | $ | (5) | | | $ | (3,319) | | | $ | (22) | | | | | $ | (3,346) | |
| OCI before reclassifications | — | | | — | | | 2 | | | | | 2 | |
| Amounts reclassified from AOCI | — | | | 55 | | | — | | | | | 55 | |
| Net current-period OCI | — | | | 55 | | | 2 | | | | | 57 | |
| Balance at June 30, 2021 | $ | (5) | | | $ | (3,264) | | | $ | (20) | | | | | $ | (3,289) | |
| | | | | | | | | | | | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2022 | Cash Flow Hedges | | Pension and Non-Pension Postretirement Benefit Plan Items(a) | | Foreign
Currency
Items | | | | Total |
| Balance at December 31, 2021 | $ | (6) | | | $ | (2,721) | | | $ | (23) | | | | | $ | (2,750) | |
| Separation of Constellation | 6 | | | 1,994 | | | 23 | | | | | 2,023 | |
| OCI before reclassifications | — | | | 2 | | | — | | | | | 2 | |
| Amounts reclassified from AOCI | — | | | 24 | | | — | | | | | 24 | |
| Net current-period OCI | — | | | 26 | | | — | | | | | 26 | |
| Balance at June 30, 2022 | $ | — | | | $ | (701) | | | $ | — | | | | | $ | (701) | |
| | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended March 31, 2023 | Cash Flow Hedges | | Pension and Non-Pension Postretirement Benefit Plan Items(a) | | Foreign
Currency
Items | | | | Total |
| Balance as of December 31, 2022 | $ | 2 | | | $ | (640) | | | $ | — | | | | | $ | (638) | |
| OCI before reclassifications | 6 | | | (10) | | | — | | | | | (4) | |
| Amounts reclassified from AOCI | — | | | 3 | | | — | | | | | 3 | |
| Net current-period OCI | 6 | | | (7) | | | — | | | | | (1) | |
| Balance as of March 31, 2023 | $ | 8 | | | $ | (647) | | | $ | — | | | | | $ | (639) | |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 13 — Changes in Accumulated Other Comprehensive Income
| | | | | | | | | | | | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2021 | Cash Flow Hedges | | Pension and Non-Pension Postretirement Benefit Plan Items(a) | | Foreign
Currency
Items | | | | Total |
| Balance at December 31, 2020 | $ | (5) | | | $ | (3,372) | | | $ | (23) | | | | | $ | (3,400) | |
| OCI before reclassifications | — | | | (2) | | | 3 | | | | | 1 | |
| Amounts reclassified from AOCI | — | | | 110 | | | — | | | | | 110 | |
| Net current-period OCI | — | | | 108 | | | 3 | | | | | 111 | |
| Balance at June 30, 2021 | $ | (5) | | | $ | (3,264) | | | $ | (20) | | | | | $ | (3,289) | |
__________(a)This AOCI component is included in the computation of net periodic pension and OPEB cost. Additionally, as of February 1, 2022, in connection with the separation, Exelon's pension and OPEB plans were remeasured. See Note 8 — Retirement Benefits for additional information. See Exelon's Statements of Operations and Comprehensive Income for individual components of AOCI.
The following table presents income tax benefit (expense) allocated to each component of Exelon's other comprehensive income (loss):
| | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended June 30, | | Six Months Ended June 30, | | |
| 2022 | | 2021 | | 2022 | | 2021 | | | | |
| Pension and non-pension postretirement benefit plans: | | | | | | | | | | | |
| Prior service benefit reclassified to periodic benefit cost | $ | — | | | $ | 1 | | | $ | — | | | $ | 2 | | | | | |
| Actuarial loss reclassified to periodic benefit cost | (3) | | | (19) | | | (8) | | | (38) | | | | | |
| Pension and non-pension postretirement benefit plans valuation adjustment | (1) | | | (1) | | | — | | | (1) | | | | | |
| | | | | | | | | | | |
| | | | | | | | | | | |
14. Supplemental Financial Information (All Registrants)
Supplemental Statement of Operations Information
The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Operations and Comprehensive Income:
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 14 — Changes in Accumulated Other Comprehensive Income
| | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended March 31, 2022 | Cash Flow Hedges | | Pension and Non-Pension Postretirement Benefit Plan Items(a) | | Foreign
Currency
Items | | | | Total |
| Balance as of December 31, 2021 | $ | (6) | | | $ | (2,721) | | | $ | (23) | | | | | $ | (2,750) | |
| Separation of Constellation | 6 | | | 1,994 | | | 23 | | | | | 2,023 | |
| | | | | | | | | |
| Amounts reclassified from AOCI | — | | | 14 | | | — | | | | | 14 | |
| Net current-period OCI | — | | | 14 | | | — | | | | | 14 | |
| Balance as of March 31, 2022 | $ | — | | | $ | (713) | | | $ | — | | | | | $ | (713) | |
__________(a)This AOCI component is included in the computation of net periodic pension and OPEB cost. Additionally, as of February 1, 2022, in connection with the separation, Exelon's pension and OPEB plans were remeasured. See Note 14 — Retirement Benefits of the 2022 Form 10-K and Note 8 — Retirement Benefits for additional information. See Exelon's Statements of Operations and Comprehensive Income for individual components of AOCI.
The following table presents Income tax benefit (expense) allocated to each component of Exelon's Other comprehensive income (loss):
| | | | | | | | | | | | | | | | | | | |
| | | Three Months Ended March 31, | | |
| | | | | 2023 | | 2022 | | | | |
| Pension and non-pension postretirement benefit plans: | | | | | | | | | | | |
| | | | | | | | | | | |
| Actuarial loss reclassified to periodic benefit cost | | | | | $ | (1) | | | $ | (5) | | | | | |
| Pension and non-pension postretirement benefit plans valuation adjustment | | | | | 3 | | | — | | | | | |
| Unrealized gain on cash flow hedges | | | | | (1) | | | — | | | | | |
| | | | | | | | | | | |
15. Supplemental Financial Information
(All Registrants) | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Taxes other than income taxes |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Three Months Ended June 30, 2022 | | | | | | | | | | | | | | | |
Utility taxes(a) | $ | 203 | | | $ | 71 | | | $ | 39 | | | $ | 20 | | | $ | 73 | | | $ | 67 | | | $ | 5 | | | $ | 1 | |
| Property | 94 | | | 10 | | | 4 | | | 46 | | | 33 | | | 23 | | | 10 | | | — | |
| Payroll | 28 | | | 7 | | | 5 | | | 4 | | | 7 | | | 1 | | | 1 | | | 1 | |
| | | | | | | | | | | | | | | |
| Three Months Ended June 30, 2021 | | | | | | | | | | | | | | | |
Utility taxes(a) | $ | 184 | | | $ | 61 | | | $ | 32 | | | $ | 20 | | | $ | 71 | | | $ | 65 | | | $ | 5 | | | $ | — | |
| Property | 86 | | | 8 | | | 4 | | | 43 | | | 31 | | | 20 | | | 10 | | | 1 | |
| Payroll | 32 | | | 6 | | | 4 | | | 5 | | | 7 | | | 1 | | | 1 | | | 1 | |
| | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2022 | | | | | | | | | | | | | | | |
Utility taxes(a) | $ | 424 | | | $ | 149 | | | $ | 77 | | | $ | 47 | | | $ | 151 | | | $ | 137 | | | $ | 12 | | | $ | 2 | |
| Property | 188 | | | 20 | | | 9 | | | 92 | | | 67 | | | 46 | | | 20 | | | 1 | |
| Payroll | 64 | | | 13 | | | 8 | | | 9 | | | 14 | | | 3 | | | 2 | | | 2 | |
| | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2021 | | | | | | | | | | | | | | | |
Utility taxes(a) | $ | 377 | | | $ | 121 | | | $ | 66 | | | $ | 45 | | | $ | 145 | | | $ | 132 | | | $ | 11 | | | $ | 1 | |
| Property | 173 | | | 16 | | | 9 | | | 85 | | | 63 | | | 42 | | | 19 | | | 1 | |
| Payroll | 64 | | | 13 | | | 8 | | | 9 | | | 14 | | | 3 | | | 3 | | | 2 | |
The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Operations and Comprehensive Income:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Taxes other than income taxes |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Three Months Ended March 31, 2023 | | | | | | | | | | | | | | | |
Utility taxes(a) | $ | 220 | | | $ | 74 | | | $ | 40 | | | $ | 29 | | | $ | 77 | | | $ | 68 | | | $ | 8 | | | $ | 1 | |
| Property | 99 | | | 10 | | | 4 | | | 50 | | | 35 | | | 24 | | | 11 | | | — | |
| Payroll | 32 | | | 7 | | | 5 | | | 5 | | | 7 | | | 2 | | | 1 | | | 1 | |
| | | | | | | | | | | | | | | |
| Three Months Ended March 31, 2022 | | | | | | | | | | | | | | | |
Utility taxes(a) | $ | 221 | | | $ | 78 | | | $ | 38 | | | $ | 27 | | | $ | 78 | | | $ | 70 | | | $ | 7 | | | $ | 1 | |
| Property | 94 | | | 10 | | | 4 | | | 46 | | | 34 | | | 23 | | | 10 | | | 1 | |
| Payroll | 37 | | | 7 | | | 4 | | | 4 | | | 7 | | | 2 | | | 1 | | | 1 | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
_________(a)The Registrants' utility taxes represent municipal and state utility taxes and gross receipts taxes related to their operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Other, Net |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Three Months Ended June 30, 2022 | | | | | | | | | | | | | | | |
| AFUDC — Equity | $ | 38 | | | $ | 9 | | | $ | 8 | | | $ | 6 | | | $ | 15 | | | $ | 11 | | | $ | 2 | | | $ | 2 | |
| Non-service net periodic benefit cost | 16 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Three Months Ended June 30, 2021 | | | | | | | | | | | | | | | |
| AFUDC — Equity | $ | 34 | | | $ | 9 | | | $ | 6 | | | $ | 7 | | | $ | 12 | | | $ | 10 | | | $ | 1 | | | $ | 1 | |
| Non-service net periodic benefit cost | 26 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2022 | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| AFUDC — Equity | $ | 74 | | | $ | 17 | | | $ | 15 | | | $ | 12 | | | $ | 30 | | | $ | 22 | | | $ | 4 | | | $ | 4 | |
| Non-service net periodic benefit cost | 33 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2021 | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| AFUDC — Equity | $ | 64 | | | $ | 13 | | | $ | 12 | | | $ | 14 | | | $ | 25 | | | $ | 20 | | | $ | 3 | | | $ | 2 | |
| Non-service net periodic benefit cost | 46 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
Supplemental Cash Flow Information
The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Cash Flows.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 1415 — Supplemental Financial Information
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Depreciation and amortization |
| Exelon(a) | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Six Months Ended June 30, 2022 | | | | | | | | | | | | | | | |
Property, plant, and equipment(b) | $ | 1,376 | | | $ | 511 | | | $ | 177 | | | $ | 235 | | | $ | 335 | | | $ | 145 | | | $ | 92 | | | $ | 83 | |
Amortization of regulatory assets(b) | 357 | | | 138 | | | 8 | | | 87 | | | 124 | | | 68 | | | 21 | | | 35 | |
Amortization of intangible assets, net(b) | 8 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
Amortization of energy contract assets and liabilities(c) | 3 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
Nuclear fuel(d) | 66 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
ARO accretion(e) | 44 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total depreciation, amortization, and accretion | $ | 1,854 | | | $ | 649 | | | $ | 185 | | | $ | 322 | | | $ | 459 | | | $ | 213 | | | $ | 113 | | | $ | 118 | |
| | | | | | | | | | | | | | | |
| Six Months Ended June 30, 2021 | | | | | | | | | | | | | | | |
Property, plant, and equipment(b) | $ | 3,043 | | | $ | 480 | | | $ | 165 | | | $ | 215 | | | $ | 309 | | | $ | 135 | | | $ | 84 | | | $ | 76 | |
Amortization of regulatory assets(b) | 291 | | | 109 | | | 8 | | | 78 | | | 95 | | | 64 | | | 20 | | | 11 | |
Amortization of intangible assets, net(b) | 29 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
Amortization of energy contract assets and liabilities(c) | 13 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
Nuclear fuel(d) | 549 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
ARO accretion(e) | 255 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total depreciation, amortization, and accretion | $ | 4,180 | | | $ | 589 | | | $ | 173 | | | $ | 293 | | | $ | 404 | | | $ | 199 | | | $ | 104 | | | $ | 87 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Other, Net |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Three Months Ended March 31, 2023 | | | | | | | | | | | | | | | |
| AFUDC — Equity | $ | 38 | | | $ | 10 | | | $ | 6 | | | $ | 3 | | | $ | 19 | | | $ | 14 | | | $ | 2 | | | $ | 3 | |
| Non-service net periodic benefit cost | (1) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Three Months Ended March 31, 2022 | | | | | | | | | | | | | | | |
| AFUDC — Equity | $ | 36 | | | $ | 8 | | | $ | 7 | | | $ | 6 | | | $ | 15 | | | $ | 11 | | | $ | 2 | | | $ | 2 | |
| Non-service net periodic benefit cost | 17 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
Supplemental Cash Flow Information
The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Cash Flows.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Depreciation, amortization, and accretion |
| Exelon(a) | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Three Months Ended March 31, 2023 | | | | | | | | | | | | | | | |
Property, plant, and equipment(b) | $ | 680 | | | $ | 267 | | | $ | 95 | | | $ | 124 | | | $ | 180 | | | $ | 76 | | | $ | 51 | | | $ | 47 | |
Amortization of regulatory assets(b) | 178 | | | 71 | | | 3 | | | 43 | | | 61 | | | 32 | | | 9 | | | 20 | |
Amortization of intangible assets, net(b) | 2 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| Total depreciation and amortization | $ | 860 | | | $ | 338 | | | $ | 98 | | | $ | 167 | | | $ | 241 | | | $ | 108 | | | $ | 60 | | | $ | 67 | |
| | | | | | | | | | | | | | | |
| Three Months Ended March 31, 2022 | | | | | | | | | | | | | | | |
Property, plant, and equipment(b) | $ | 726 | | | $ | 254 | | | $ | 88 | | | $ | 117 | | | $ | 164 | | | $ | 72 | | | $ | 45 | | | $ | 41 | |
Amortization of regulatory assets(b) | 179 | | | 67 | | | 4 | | | 54 | | | 54 | | | 36 | | | 12 | | | 6 | |
Amortization of intangible assets, net(b) | 6 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
Amortization of energy contract assets and liabilities(c) | 3 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
Nuclear fuel(d) | 66 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
ARO accretion(e) | 44 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total depreciation, amortization, and accretion | $ | 1,024 | | | $ | 321 | | | $ | 92 | | | $ | 171 | | | $ | 218 | | | $ | 108 | | | $ | 57 | | | $ | 47 | |
__________
(a)Exelon's 2022 amounts include amounts related to Generation prior to the separation. See Note 2 — Discontinued Operations for additional information.
(b)Included in Depreciation and amortization in the Registrants' Consolidated Statements of Operations and Comprehensive Income.
(c)Included in OperatingElectric operating revenues or Purchased power and fuel expense in Exelon’s Consolidated Statements of Operations and Comprehensive Income.
(d)Included in Purchased fuel expense in Exelon's Consolidated Statement of Operations and Comprehensive Income.
(e)Included in Operating and maintenance expense in Exelon's Consolidated Statement of Operations and Comprehensive Income.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 1415 — Supplemental Financial Information
| | | Other non-cash operating activities | | Other non-cash operating activities |
| | Exelon(a) | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE | | Exelon(a) | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Six Months Ended June 30, 2022 | | | | | | | | | | | | | | | | |
| Pension and non-pension postretirement benefit costs | $ | 86 | | | $ | 30 | | | $ | (4) | | | $ | 22 | | | $ | 26 | | | $ | 4 | | | $ | 2 | | | $ | 6 | | |
| Three Months Ended March 31, 2023 | | Three Months Ended March 31, 2023 | | | | | | | | | | | | | | | |
| Pension and OPEB costs (benefit) | | Pension and OPEB costs (benefit) | $ | 45 | | | $ | 6 | | | $ | (3) | | | $ | 14 | | | $ | 24 | | | $ | 8 | | | $ | 4 | | | $ | 4 | |
| Allowance for credit losses | | Allowance for credit losses | 70 | | | — | | | 37 | | | 18 | | | 15 | | | 7 | | | 5 | | | 3 | |
| True-up adjustments to decoupling mechanisms and formula rates(b) | | True-up adjustments to decoupling mechanisms and formula rates(b) | (282) | | | (153) | | | 4 | | | (65) | | | (68) | | | (39) | | | (11) | | | (18) | |
| | Long-term incentive plan | | Long-term incentive plan | 2 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | Amortization of operating ROU asset | | Amortization of operating ROU asset | 10 | | | 1 | | | — | | | 1 | | | 7 | | | 1 | | | 2 | | | 1 | |
| Change in environmental liabilities | | Change in environmental liabilities | 25 | | | — | | | — | | | — | | | 25 | | | 25 | | | — | | | — | |
| | AFUDC — Equity | | AFUDC — Equity | (38) | | | (10) | | | (6) | | | (3) | | | (19) | | | (14) | | | (2) | | | (3) | |
| | Three Months Ended March 31, 2022 | | Three Months Ended March 31, 2022 | | |
| Pension and OPEB costs (benefit) | | Pension and OPEB costs (benefit) | $ | 44 | | | $ | 16 | | | $ | (2) | | | $ | 12 | | | $ | 13 | | | $ | 2 | | | $ | 1 | | | $ | 3 | |
| Allowance for credit losses | Allowance for credit losses | 96 | | | 29 | | | 21 | | | 18 | | | 29 | | | 16 | | | 6 | | | 7 | | Allowance for credit losses | 78 | | | 17 | | | 27 | | | 18 | | | 18 | | | 9 | | | 6 | | | 3 | |
| Other decommissioning-related activity | Other decommissioning-related activity | 36 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Other decommissioning-related activity | 36 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Energy-related options | Energy-related options | 60 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Energy-related options | 60 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
True-up adjustments to decoupling mechanisms and formula rates(b) | True-up adjustments to decoupling mechanisms and formula rates(b) | (27) | | | (75) | | | (6) | | | 32 | | | 22 | | | 7 | | | 3 | | | 12 | | True-up adjustments to decoupling mechanisms and formula rates(b) | (29) | | | (40) | | | (6) | | | 12 | | | 5 | | | 7 | | | 1 | | | (3) | |
| | Long-term incentive plan | Long-term incentive plan | 40 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Long-term incentive plan | 25 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| | Amortization of operating ROU asset | Amortization of operating ROU asset | 38 | | | 1 | | | — | | | 14 | | | 14 | | | 4 | | | 4 | | | 2 | | Amortization of operating ROU asset | 23 | | | 1 | | | — | | | 7 | | | 7 | | | 2 | | | 2 | | | 1 | |
| | AFUDC — Equity | AFUDC — Equity | (74) | | | (17) | | | (15) | | | (12) | | | (30) | | | (22) | | | (4) | | | (4) | | AFUDC — Equity | (36) | | | (8) | | | (7) | | | (6) | | | (15) | | | (11) | | | (2) | | | (2) | |
| | Six Months Ended June 30, 2021 | | | |
| Pension and non-pension postretirement benefit costs | $ | 196 | | | $ | 64 | | | $ | 4 | | | $ | 29 | | | $ | 24 | | | $ | 3 | | | $ | 1 | | | $ | 5 | | |
| Allowance for credit losses | 100 | | | 24 | | | 17 | | | 4 | | | 9 | | | 5 | | | 2 | | | 2 | | |
| Other decommissioning-related activity | (636) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | |
| Energy-related options | 20 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | |
True-up adjustments to decoupling mechanisms and formula rates(b) | (176) | | | (64) | | | (17) | | | (8) | | | (88) | | | (46) | | | (19) | | | (23) | | |
| | Long-term incentive plan | 62 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | |
| | Amortization of operating ROU asset | 83 | | | 1 | | | — | | | 15 | | | 14 | | | 3 | | | 5 | | | 2 | | |
| | AFUDC — Equity | (64) | | | (13) | | | (12) | | | (14) | | | (25) | | | (20) | | | (3) | | | (2) | | |
__________
(a)Exelon's 2022 amounts include amounts related to Generation prior to the separation. See Note 2 — Discontinued Operations for additional information.
(b)For ComEd, reflects the true-up adjustments in regulatory assets and liabilities associated with its distribution, energy efficiency, distributed generation, and transmission formula rates. For PECO, reflects the change in regulatory assets and liabilities associated with its transmission formula rates. For BGE, Pepco, DPL, and ACE, reflects the change in regulatory assets and liabilities associated with their decoupling mechanisms and transmission formula rates. For PECO, reflects the change in regulatory assets and liabilities associated with its transmission formula rates. See Note 3 — Regulatory Matters of the 2021 Recast2022 Form 10-K for additional information.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 1415 — Supplemental Financial Information
The following tables provide a reconciliation of cash, cash equivalents, and restricted cash reported within the Registrants’ Consolidated Balance Sheets that sum to the total of the same amounts in their Consolidated Statements of Cash Flows.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| June 30, 2022 | | | | | | | | | | | | | | | |
| Cash and cash equivalents | $ | 816 | | | $ | 120 | | | $ | 23 | | | $ | 354 | | | $ | 278 | | | $ | 14 | | | $ | 26 | | | $ | 233 | |
| Restricted cash and cash equivalents | 961 | | | 384 | | | 9 | | | 205 | | | 341 | | | 117 | | | 223 | | | — | |
| Restricted cash included in other long-term assets | 59 | | | 59 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total cash, restricted cash, and cash equivalents | $ | 1,836 | | | $ | 563 | | | $ | 32 | | | $ | 559 | | | $ | 619 | | | $ | 131 | | | $ | 249 | | | $ | 233 | |
| | | | | | | | | | | | | | | |
| December 31, 2021 | | | | | | | | | | | | | | | |
| Cash and cash equivalents | $ | 672 | | | $ | 131 | | | $ | 36 | | | $ | 51 | | | $ | 136 | | | $ | 34 | | | $ | 28 | | | $ | 29 | |
| Restricted cash and cash equivalents | 321 | | | 210 | | | 8 | | | 4 | | | 77 | | | 34 | | | 43 | | | — | |
| Restricted cash included in other long-term assets | 44 | | | 43 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Cash, restricted cash, and cash equivalents from discontinued operations | 582 | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total cash, restricted cash, and cash equivalents | $ | 1,619 | | | $ | 384 | | | $ | 44 | | | $ | 55 | | | $ | 213 | | | $ | 68 | | | $ | 71 | | | $ | 29 | |
| | | | | | | | | | | | | | | |
| June 30, 2021 | | | | | | | | | | | | | | | |
| Cash and cash equivalents | $ | 1,578 | | | $ | 71 | | | $ | 376 | | | $ | 368 | | | $ | 61 | | | $ | 17 | | | $ | 17 | | | $ | 11 | |
| Restricted cash and cash equivalents | 379 | | | 240 | | | 8 | | | 3 | | | 42 | | | 33 | | | 5 | | | 3 | |
| Restricted cash included in other long-term assets | 52 | | | 43 | | | — | | | — | | | 9 | | | — | | | — | | | 9 | |
Total cash, restricted cash, and cash equivalents(a) | $ | 2,009 | | | $ | 354 | | | $ | 384 | | | $ | 371 | | | $ | 112 | | | $ | 50 | | | $ | 22 | | | $ | 23 | |
| | | | | | | | | | | | | | | |
| December 31, 2020 | | | | | | | | | | | | | | | |
| Cash and cash equivalents | $ | 432 | | | $ | 83 | | | $ | 19 | | | $ | 144 | | | $ | 111 | | | $ | 30 | | | $ | 15 | | | $ | 17 | |
| Restricted cash and cash equivalents | 349 | | | 279 | | | 7 | | | 1 | | | 39 | | | 35 | | | — | | | 3 | |
| Restricted cash included in other long-term assets | 53 | | | 43 | | | — | | | — | | | 10 | | | — | | | — | | | 10 | |
| Cash, restricted cash, and cash equivalents from discontinued operations | 332 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total cash, restricted cash, and cash equivalents | $ | 1,166 | | | $ | 405 | | | $ | 26 | | | $ | 145 | | | $ | 160 | | | $ | 65 | | | $ | 15 | | | $ | 30 | |
__________
(a)Exelon's amounts include amounts related to Generation prior to the separation. See Note 2 — Discontinued Operations for additional information. | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| March 31, 2023 | | | | | | | | | | | | | | | |
| Cash and cash equivalents | $ | 522 | | | $ | 75 | | | $ | 27 | | | $ | 20 | | | $ | 367 | | | $ | 126 | | | $ | 142 | | | $ | 71 | |
| Restricted cash and cash equivalents | 381 | | | 323 | | | 9 | | | 1 | | | 29 | | | 27 | | | 1 | | | — | |
| Restricted cash included in other deferred debits and other assets | 180 | | | 180 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total cash, restricted cash, and cash equivalents | $ | 1,083 | | | $ | 578 | | | $ | 36 | | | $ | 21 | | | $ | 396 | | | $ | 153 | | | $ | 143 | | | $ | 71 | |
| | | | | | | | | | | | | | | |
| December 31, 2022 | | | | | | | | | | | | | | | |
| Cash and cash equivalents | $ | 407 | | | $ | 67 | | | $ | 59 | | | $ | 43 | | | $ | 198 | | | $ | 45 | | | $ | 31 | | | $ | 72 | |
| Restricted cash and cash equivalents | 566 | | | 327 | | | 9 | | | 24 | | | 175 | | | 54 | | | 121 | | | — | |
| Restricted cash included in other deferred debits and other assets | 117 | | | 117 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total cash, restricted cash, and cash equivalents | $ | 1,090 | | | $ | 511 | | | $ | 68 | | | $ | 67 | | | $ | 373 | | | $ | 99 | | | $ | 152 | | | $ | 72 | |
| | | | | | | | | | | | | | | |
| March 31, 2022 | | | | | | | | | | | | | | | |
| Cash and cash equivalents | $ | 2,476 | | | $ | 343 | | | $ | 26 | | | $ | 41 | | | $ | 796 | | | $ | 502 | | | $ | 120 | | | $ | 168 | |
| Restricted cash and cash equivalents | 430 | | | 246 | | | 8 | | | 34 | | | 106 | | | 34 | | | 73 | | | — | |
| Restricted cash included in other deferred debits and other assets | 92 | | | 92 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total cash, restricted cash, and cash equivalents | $ | 2,998 | | | $ | 681 | | | $ | 34 | | | $ | 75 | | | $ | 902 | | | $ | 536 | | | $ | 193 | | | $ | 168 | |
| | | | | | | | | | | | | | | |
| December 31, 2021 | | | | | | | | | | | | | | | |
| Cash and cash equivalents | $ | 672 | | | $ | 131 | | | $ | 36 | | | $ | 51 | | | $ | 136 | | | $ | 34 | | | $ | 28 | | | $ | 29 | |
| Restricted cash and cash equivalents | 321 | | | 210 | | | 8 | | | 4 | | | 77 | | | 34 | | | 43 | | | — | |
| Restricted cash included in other deferred debits and other assets | 44 | | | 43 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Cash, restricted cash, and cash equivalents from discontinued operations | 582 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Total cash, restricted cash, and cash equivalents | $ | 1,619 | | | $ | 384 | | | $ | 44 | | | $ | 55 | | | $ | 213 | | | $ | 68 | | | $ | 71 | | | $ | 29 | |
For additional information on restricted cash see Note 1 — Significant Accounting Policies of the 2021 Recast2022 Form 10-K.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 14 — Supplemental Financial Information
Supplemental Balance Sheet Information
The following table provides additional information about material items recorded in the Registrants' Consolidated Balance Sheets.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Accrued expenses |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| June 30, 2022 | | | | | | | | | | | | | | | |
Compensation-related accruals(a) | $ | 428 | | | $ | 109 | | | $ | 57 | | | $ | 54 | | | $ | 82 | | | $ | 26 | | | $ | 16 | | | $ | 13 | |
| Taxes accrued | 243 | | | 94 | | | 60 | | | 31 | | | 84 | | | 57 | | | 12 | | | 11 | |
| Interest accrued | 331 | | | 124 | | | 40 | | | 44 | | | 59 | | | 31 | | | 9 | | | 14 | |
| | | | | | | | | | | | | | | |
| December 31, 2021 | | | | | | | | | | | | | | | |
Compensation-related accruals(a) | $ | 596 | | | $ | 155 | | | $ | 77 | | | $ | 78 | | | $ | 113 | | | $ | 35 | | | $ | 20 | | | $ | 17 | |
| Taxes accrued | 253 | | | 94 | | | 14 | | | 53 | | | 96 | | | 88 | | | 9 | | | 11 | |
| Interest accrued | 297 | | | 116 | | | 41 | | | 44 | | | 52 | | | 28 | | | 8 | | | 11 | |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 15 — Supplemental Financial Information
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Accrued expenses |
| Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| March 31, 2023 | | | | | | | | | | | | | | | |
Compensation-related accruals(a) | $ | 359 | | | $ | 107 | | | $ | 43 | | | $ | 42 | | | $ | 59 | | | $ | 18 | | | $ | 11 | | | $ | 10 | |
| Taxes accrued | 214 | | | 102 | | | 3 | | | 83 | | | 94 | | | 67 | | | 14 | | | 16 | |
| Interest accrued | 373 | | | 78 | | | 44 | | | 45 | | | 75 | | | 35 | | | 22 | | | 16 | |
| | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | |
| December 31, 2022 | | | | | | | | | | | | | | | |
Compensation-related accruals(a) | $ | 613 | | | $ | 179 | | | $ | 81 | | | $ | 79 | | | $ | 104 | | | $ | 29 | | | $ | 20 | | | $ | 16 | |
| Taxes accrued | 211 | | | 92 | | | 10 | | | 34 | | | 70 | | | 52 | | | 8 | | | 12 | |
| Interest accrued | 338 | | | 124 | | | 47 | | | 42 | | | 61 | | | 32 | | | 9 | | | 14 | |
__________
(a)Primarily includes accrued payroll, bonuses and other incentives, vacation, and benefits.
15.16. Related Party Transactions (All Registrants)
Utility Registrants' expense with Generation
The Utility Registrants incurred expenses from transactions with the Generation affiliate as described in the footnotes to the table below prior to separation on February 1, 2022. Such expenses were primarily recorded as Purchased power from affiliatesaffiliate and an immaterial amount recorded as Operating and maintenance expense from affiliates at the Utility Registrants:Registrants. Effective February 1, 2022, Generation is no longer considered a related party.
| | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended June 30, | | Six Months Ended June 30, |
| | 2022 | | 2021 | | 2022 | | 2021 |
ComEd(a) | $ | — | | | $ | 78 | | | $ | 59 | | | $ | 163 | |
PECO(b) | — | | | 41 | | | 33 | | | 83 | |
BGE(c) | — | | | 58 | | | 18 | | | 130 | |
| PHI | — | | | 77 | | | 51 | | | 176 | |
Pepco(d) | — | | | 55 | | | 39 | | | 130 | |
DPL(e) | — | | | 17 | | | 10 | | | 37 | |
ACE(f) | — | | | 5 | | | 2 | | | 9 | |
| | | | | | | | | |
| Three Months Ended March 31, | | |
| 2022 | | | | |
ComEd(a) | $ | 59 | | | | | |
PECO(b) | 33 | | | | | |
BGE(c) | 18 | | | | | |
| PHI | 51 | | | | | |
Pepco(d) | 39 | | | | | |
DPL(e) | 10 | | | | | |
ACE(f) | 2 | | | | | |
__________(a)ComEd had an ICC-approved RFP contract with Generation to provide a portion of ComEd’s electric supply requirements. ComEd also purchased RECs and ZECs from Generation.
(b)PECO received electric supply from Generation under contracts executed through PECO’s competitive procurement process. In addition, PECO had a ten-year agreement with Generation to sell solar AECs.
(c)BGE received a portion of its energy requirements from Generation under its MDPSC-approved market-based SOS and gas commodity programs.
(d)Pepco received electric supply from Generation under contracts executed through Pepco's competitive procurement process approved by the MDPSC and DCPSC.
(e)DPL received a portion of its energy requirements from Generation under its MDPSC and DEPSC approved market-based SOS commodity programs.
(f)ACE received electric supply from Generation under contracts executed through ACE's competitive procurement process approved by the NJBPU.
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 1516 — Related Party Transactions
Service Company Costs for Corporate Support
The Registrants receive a variety of corporate support services from BSC. Pepco, DPL, and ACE also receive corporate support services from PHISCO. See Note 1 — Significant Accounting Policies for additional information regarding BSC and PHISCO.
The following table presents the service company costs allocated to the Registrants:
| | | Operating and maintenance from affiliates | | Capitalized costs | | Operating and maintenance from affiliates | | Capitalized costs |
| | Three Months Ended June 30, | | Six Months Ended June 30, | | Three Months Ended June 30, | | Six Months Ended June 30, | | Three Months Ended March 31, | | | Three Months Ended March 31, | |
| | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 | | 2022 | | 2021 | | 2023 | | 2022 | | | 2023 | | 2022 | |
| Exelon | Exelon | | | | | | | | | | | | | | | | | Exelon | | | | | | | | | | |
| BSC | BSC | | $ | 139 | | | $ | 114 | | | $ | 344 | | | $ | 249 | | BSC | | | | $ | 175 | | | $ | 205 | | |
| PHISCO | PHISCO | | 21 | | | 17 | | | 40 | | | 36 | | PHISCO | | | | 24 | | | 19 | | |
| ComEd | ComEd | | ComEd | | | | |
| BSC | BSC | | $ | 80 | | | $ | 72 | | | $ | 165 | | | $ | 143 | | | 67 | | | 45 | | | 152 | | | 102 | | BSC | | $ | 83 | | | $ | 85 | | | | 81 | | | 85 | | |
| PECO | PECO | | PECO | | | | |
| BSC | BSC | | 47 | | | 40 | | | 96 | | | 80 | | | 20 | | | 17 | | | 56 | | | 44 | | BSC | | 51 | | | 49 | | | | 30 | | | 36 | | |
| BGE | BGE | | BGE | | | | |
| BSC | BSC | | 51 | | | 45 | | | 102 | | | 88 | | | 22 | | | 20 | | | 60 | | | 43 | | BSC | | 54 | | | 51 | | | | 24 | | | 38 | | |
| PHI | PHI | | PHI | | | | |
| BSC | BSC | | 46 | | | 37 | | | 96 | | | 76 | | | 30 | | | 32 | | | 76 | | | 60 | | BSC | | 42 | | | 50 | | | | 40 | | | 46 | | |
| PHISCO | PHISCO | | — | | | — | | | — | | | — | | | 21 | | | 17 | | | 40 | | | 36 | | PHISCO | | — | | | — | | | | 24 | | | 19 | | |
| Pepco | Pepco | | Pepco | | | | |
| BSC | BSC | | 27 | | | 23 | | | 56 | | | 45 | | | 11 | | | 13 | | | 28 | | | 25 | | BSC | | 27 | | | 29 | | | | 14 | | | 17 | | |
| PHISCO | PHISCO | | 29 | | | 28 | | | 58 | | | 57 | | | 8 | | | 7 | | | 16 | | | 15 | | PHISCO | | 30 | | | 29 | | | | 11 | | | 8 | | |
| | DPL | DPL | | DPL | | | | |
| BSC | BSC | | 17 | | | 15 | | | 35 | | | 29 | | | 9 | | | 10 | | | 23 | | | 19 | | BSC | | 17 | | | 18 | | | | 10 | | | 14 | | |
| PHISCO | PHISCO | | 25 | | | 24 | | | 49 | | | 49 | | | 7 | | | 5 | | | 13 | | | 11 | | PHISCO | | 24 | | | 24 | | | | 7 | | | 6 | | |
| | ACE | ACE | | ACE | | | | |
| BSC | BSC | | 14 | | | 12 | | | 29 | | | 24 | | | 10 | | | 8 | | | 25 | | | 15 | | BSC | | 14 | | | 15 | | | | 14 | | | 15 | | |
| PHISCO | PHISCO | | 22 | | | 21 | | | 43 | | | 43 | | | 6 | | | 5 | | | 11 | | | 10 | | PHISCO | | 22 | | | 21 | | | | 6 | | | 5 | | |
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 1516 — Related Party Transactions
Current Receivables from/Payables to affiliates
The following tables present current receivablesReceivables from affiliates and current payablesPayables to affiliates:
June 30, 2022March 31, 2023
| | | | Receivables from affiliates: | | | | Receivables from affiliates: | |
| | Payables to affiliates: | | ComEd | | PECO | | BGE | | | Pepco | | DPL | | ACE | | BSC | | PHISCO | | Other | | Total | | Payables to affiliates: | | ComEd | | PECO | | BGE | | | Pepco | | DPL | | ACE | | BSC | | PHISCO | | Other | | Total |
| ComEd | ComEd | | | | $ | — | | | $ | — | | | | $ | — | | | $ | — | | | $ | — | | | $ | 57 | | | $ | — | | | $ | 8 | | | $ | 65 | | ComEd | | | | $ | — | | | $ | — | | | | $ | — | | | $ | — | | | $ | — | | | $ | 78 | | | $ | — | | | $ | 6 | | | $ | 84 | |
| PECO | PECO | | $ | — | | | — | | | | — | | | — | | | — | | | 25 | | | — | | | 4 | | | 29 | | PECO | | $ | — | | | — | | | | — | | | — | | | 1 | | | 39 | | | — | | | 8 | | | 48 | |
| BGE | BGE | | — | | | — | | | | — | | | — | | | — | | | 28 | | | — | | | 2 | | | 30 | | BGE | | — | | | — | | | | — | | | — | | | — | | | 35 | | | — | | | 2 | | | 37 | |
| PHI | PHI | | — | | | — | | | — | | | | — | | | — | | | — | | | 5 | | | — | | | 10 | | | 15 | | PHI | | — | | | — | | | — | | | | — | | | — | | | — | | | 7 | | | — | | | 10 | | | 17 | |
| Pepco | Pepco | | — | | | — | | | — | | | | | — | | | 1 | | | 14 | | | 13 | | | 1 | | | 29 | | Pepco | | — | | | — | | | — | | | | | — | | | — | | | 22 | | | 15 | | | 1 | | | 38 | |
| DPL | DPL | | — | | | — | | | — | | | | 9 | | | — | | | 9 | | | 10 | | | 1 | | | 29 | | DPL | | — | | | 1 | | | — | | | | — | | | — | | | 13 | | | 12 | | | — | | | 26 | |
| ACE | ACE | | — | | | — | | | — | | | | — | | | — | | | 9 | | | 10 | | | 1 | | | 20 | | ACE | | — | | | 1 | | | — | | | | 1 | | | — | | | 13 | | | 11 | | | — | | | 26 | |
| Other | Other | | 3 | | | — | | | — | | | | — | | | — | | | — | | | — | | | — | | | 3 | | Other | | 3 | | | — | | | — | | | | — | | | — | | | 1 | | | — | | | 1 | | | 5 | |
| Total | Total | | $ | 3 | | | $ | — | | | $ | — | | | | $ | 9 | | | $ | — | | | $ | 1 | | | $ | 147 | | | $ | 33 | | | $ | 27 | | | $ | 220 | | Total | | $ | 3 | | | $ | 2 | | | $ | — | | | | $ | 1 | | | $ | — | | | $ | 2 | | | $ | 207 | | | $ | 39 | | | $ | 27 | | | $ | 281 | |
|
December 31, 20212022
| | | | Receivables from affiliates: | | | | Receivables from affiliates: | |
| | Payables to affiliates: | | ComEd | | PECO | | BGE | | | Pepco | | DPL | | ACE | | Generation | | BSC | | PHISCO | | Other | | Total | | Payables to affiliates: | | ComEd | | PECO | | BGE | | | Pepco | | DPL | | ACE | | BSC | | PHISCO | | Other | | Total |
| ComEd | ComEd | | | | $ | — | | | $ | — | | | | $ | — | | | $ | — | | | $ | — | | | $ | 41 | | | $ | 71 | | | $ | — | | | $ | 9 | | | $ | 121 | | ComEd | | | | $ | — | | | $ | — | | | | $ | — | | | $ | — | | | $ | — | | | $ | 66 | | | $ | — | | | $ | 8 | | | $ | 74 | |
| PECO | PECO | | $ | — | | | — | | | | — | | | — | | | — | | | 30 | | | 36 | | | — | | | 4 | | | 70 | | PECO | | $ | — | | | — | | | | — | | | — | | | — | | | 39 | | | — | | | 3 | | | 42 | |
| BGE | BGE | | — | | | — | | | | | — | | | — | | | — | | | 4 | | | 41 | | | — | | | 3 | | | 48 | | BGE | | — | | | — | | | | | — | | | — | | | — | | | 38 | | | — | | | 1 | | | 39 | |
| PHI | PHI | | — | | | 1 | | | — | | | | — | | | — | | | 1 | | | — | | | 5 | | | — | | | 9 | | | 16 | | PHI | | — | | | — | | | — | | | | — | | | — | | | — | | | 4 | | | — | | | 10 | | | 14 | |
| Pepco | Pepco | | — | | | — | | | 1 | | | | 1 | | | 1 | | | 20 | | | 21 | | | 12 | | | 3 | | | 59 | | Pepco | | — | | | — | | | — | | | | — | | | — | | | 20 | | | 13 | | | 1 | | | 34 | |
| DPL | DPL | | — | | | — | | | — | | | | — | | | — | | | 4 | | | 17 | | | 11 | | | 1 | | | 33 | | DPL | | — | | | 2 | | | — | | | | — | | | — | | | 12 | | | 8 | | | — | | | 22 | |
| ACE | ACE | | — | | | — | | | — | | | | — | | | — | | | 7 | | | 13 | | | 9 | | | 2 | | | 31 | | ACE | | — | | | 2 | | | — | | | | — | | | — | | | 14 | | | 9 | | | 1 | | | 26 | |
| Generation | | 13 | | | — | | | — | | | | — | | | — | | | — | | | 102 | | | — | | | 16 | | | 131 | | |
| Other | Other | | 3 | | | — | | | — | | | | — | | | — | | | — | | | 11 | | | — | | | — | | | 14 | | Other | | 3 | | | — | | | — | | | | — | | | — | | | 1 | | | — | | | — | | | 4 | |
| Total | Total | | $ | 16 | | | $ | 1 | | | $ | 1 | | | | $ | — | | | $ | 1 | | | $ | 2 | | | $ | 117 | | | $ | 306 | | | $ | 32 | | | $ | 47 | | | $ | 523 | | Total | | $ | 3 | | | $ | 4 | | | $ | — | | | | $ | — | | | $ | — | | | $ | 1 | | | $ | 193 | | | $ | 30 | | | $ | 24 | | | $ | 255 | |
|
Borrowings from Exelon/PHI intercompany money pool
To provide an additional short-term borrowing option that will generally be more favorable to the borrowing participants than the cost of external financing both Exelon and PHI operate an intercompany money pool. ComEd, PECO and PHI Corporate participate in the Exelon intercompany money pool. Pepco, DPL, and ACE participate in the PHI intercompany money pool.
Noncurrent Receivables from affiliates
ComEd and PECO have noncurrent receivables with Generation as a result of the nuclear decommissioning contractual construct whereby, to the extent NDT funds are greater than the underlying ARO at the end of decommissioning, such amounts are due back to ComEd and PECO, as applicable, for payment to their respective customers. The receivables are recorded in Receivable related to Regulatory Agreement Units as of June 30, 2022 and in noncurrent Receivables from affiliates as of December 31, 2021. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements of the 2021 Recast Form 10-K for additional information.
Long-term debt to financing trusts
The following table presents Long-term debt to financing trusts:
COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)
Note 15 — Related Party Transactions
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| June 30, 2022 | | December 31, 2021 |
| Exelon | | ComEd | | PECO | | Exelon | | ComEd | | PECO |
| ComEd Financing III | $ | 206 | | | $ | 205 | | | $ | — | | | $ | 206 | | | $ | 205 | | | $ | — | |
| PECO Trust III | 81 | | | — | | | 81 | | | 81 | | | — | | | 81 | |
| PECO Trust IV | 103 | | | — | | | 103 | | | 103 | | | — | | | 103 | |
| Total | $ | 390 | | | $ | 205 | | | $ | 184 | | | $ | 390 | | | $ | 205 | | | $ | 184 | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| March 31, 2023 | | December 31, 2022 |
| Exelon | | ComEd | | PECO | | Exelon | | ComEd | | PECO |
| ComEd Financing III | $ | 206 | | | $ | 205 | | | $ | — | | | $ | 206 | | | $ | 205 | | | $ | — | |
| PECO Trust III | 81 | | | — | | | 81 | | | 81 | | | — | | | 81 | |
| PECO Trust IV | 103 | | | — | | | 103 | | | 103 | | | — | | | 103 | |
| Total | $ | 390 | | | $ | 205 | | | $ | 184 | | | $ | 390 | | | $ | 205 | | | $ | 184 | |
ITEM 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
(Dollars in millions except per share data, unless otherwise noted)
Exelon
Executive Overview
Exelon is a utility services holding company engaged in the energy distributiontransmission and transmissiondistribution businesses through ComEd, PECO, BGE, Pepco, DPL, and ACE.
Exelon has six reportable segments consisting of ComEd, PECO, BGE, Pepco, DPL, and ACE. See Note 1 — Significant Accounting Policies and Note 5 — Segment Information of the Combined Notes to Consolidated Financial Statements for additional information regarding Exelon's principal subsidiaries and reportable segments.
Exelon’s consolidated financial information includes the results of its seven separate operating subsidiary registrants, ComEd, PECO, BGE, PHI, Pepco, DPL, and ACE, which, along with Exelon, are collectively referred to as the Registrants. The following combined Management’s Discussion and Analysis of Financial Condition and Results of Operations is separately filed by Exelon, ComEd, PECO, BGE, PHI, Pepco, DPL, and ACE. However, none of the Registrants makes any representation as to information related solely to any of the other Registrants.
Financial Results of Operations
GAAP Results of Operations. The following table sets forth Exelon's GAAP consolidated Net income attributable to common shareholders from continuing operations and the Utility Registrants' Net income for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 2021.2022. For additional information regarding the financial results for the three and six months ended June 30,March 31, 2023 and 2022 and 2021 see the discussions of Results of Operations by Registrant.
| | | Three Months Ended June 30, | | Favorable (Unfavorable) Variance | | Six Months Ended June 30, | | Favorable (Unfavorable) Variance | | | Three Months Ended March 31, | | Favorable (Unfavorable) Variance |
| | 2022 | | 2021 | | 2022 | | 2021 | | | | 2023 | | 2022 | |
| Exelon | Exelon | $ | 465 | | | $ | 326 | | | $ | 139 | | | $ | 946 | | | $ | 851 | | | $ | 95 | | Exelon | | $ | 669 | | | $ | 481 | | | $ | 188 | |
| ComEd | ComEd | 227 | | | 192 | | | 35 | | | 415 | | | 390 | | | 25 | | ComEd | | 241 | | | 188 | | | 53 | |
| PECO | PECO | 133 | | | 104 | | | 29 | | | 339 | | | 271 | | | 68 | | PECO | | 166 | | | 206 | | | (40) | |
| BGE | BGE | 37 | | | 45 | | | (8) | | | 234 | | | 254 | | | (20) | | BGE | | 200 | | | 198 | | | 2 | |
| PHI | PHI | 100 | | | 141 | | | (41) | | | 230 | | | 269 | | | (39) | | PHI | | 155 | | | 130 | | | 25 | |
| Pepco | Pepco | 70 | | | 75 | | | (5) | | | 116 | | | 134 | | | (18) | | Pepco | | 65 | | | 46 | | | 19 | |
| DPL | DPL | 21 | | | 30 | | | (9) | | | 77 | | | 86 | | | (9) | | DPL | | 60 | | | 56 | | | 4 | |
| ACE | ACE | 11 | | | 37 | | | (26) | | | 37 | | | 51 | | | (14) | | ACE | | 33 | | | 26 | | | 7 | |
Other(a) | Other(a) | (32) | | | (156) | | | 124 | | | (272) | | | (333) | | | 61 | | Other(a) | | (93) | | | (241) | | | 148 | |
__________
(a)PrimarilyOther primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities, and other financing and investinginvestment activities.
The separation of Constellation, including Generation and its subsidiaries, meets the criteria for discontinued operations and as such, Generation's results of operations are presented as discontinued operations and have been excluded from Exelon's continuing operations for all periods presented.the three months ended March 31, 2022 presented in the table above. See Note 1 — Significant Accounting Policies and Note 2 — Discontinued Operations for additional information.
Accounting rules require that certain BSC costs previously allocated to Generation be presented as part of Exelon’s continuing operations as these costs do not qualify as expenses of the discontinued operations. Such costs are included in Other in the table above. See further discussion below.
Three Months Ended June 30, 2022 Compared to Three Months Ended June 30, 2021. Net income attributable to common shareholders from continuing operations increased by $139above and were $28 million and dilutedon a pre-tax basis, for the three months ended March 31, 2022.
earnings per average common share from continuing operations increased to $0.47 in 2022 from $0.33 in 2021 primarily due to:
•Higher electric distribution earnings from higher allowed electric distribution ROE due to an increase in treasury rates and higher rate base at ComEd;
•The favorable impacts of rate increases at PECO, BGE, and PHI; and
•Lower BSC costs, which were previously allocated to Generation but do not qualify as expenses of the discontinued operations per the accounting rules. Such costs, on a pre-tax basis, were $99 million for the three months ended June 30, 2021.
The increases were partially offset by:
•The absence of favorable weather and volume as a result of the CIP at ACE;
•Higher depreciation expense at BGE and PHI;
•Higher credit loss expense at PHI; and
•Higher interest expense at Exelon Corporate.
SixThree Months Ended June 30, 2022March 31, 2023 Compared to SixThree Months Ended June 30, 2021.March 31, 2022. Net income attributable to common shareholders from continuing operations increased by $95$188 million and diluted earnings per average common share from continuing operations increased to $0.96$0.67 in 20222023 from $0.87$0.49 in 20212022 primarily due to:
•Higher electric distribution formula rate earnings from higher allowed electric distribution ROE due to an increase in U.S. treasury rates and impacts of higher rate base at ComEd;
•The favorable impacts of rate increases at PECO, BGE, and PHI;
•Lower BSC costs presented in Exelon’s continuing operations, which were previously allocated to Generation but dodid not qualify as expenses of the discontinued operation expenses per the accounting rules. Suchrules; and
•Carrying costs on a pre-tax basis, were $28 million for the period in 2022 priorrelated to the separation on February 1, 2022 (January 1, 2022 to January 31, 2022) and $206 million for the six months ended June 30, 2021.CMC regulatory assets at ComEd.
The increases were partially offset by:
•An income tax expense recorded in connection with the separation primarily due to the long-term marginal state income tax rate change, the recognition of valuation allowances against the net deferred tax assets positions for certain standalone state filing jurisdictions,Unfavorable weather at PECO and nondeductible transaction costs partially offset by a one-time impact associated with a state tax benefit;PHI;
•The absence of favorable weatherHigher interest expense at BGE and volume as a result of the CIPExelon Corporate;
•An increase in environmental liabilities at ACE;Pepco;
•Higher depreciation expense at PECO, BGE,PECO; and PHI;
•Higher credit loss expense at BGE and PHI;
•Higher storm costs at PHI; and
•Higher interest expense at PHI and Exelon Corporate.PECO.
Adjusted (non-GAAP) Operating Earnings. In addition to netNet income, Exelon evaluates its operating performance using the measure of Adjusted (non-GAAP) operating earnings because management believes it represents earnings directly related to the ongoing operations of the business. Adjusted (non-GAAP) operating earnings exclude certain costs, expenses, gains and losses, and other specified items. This information is intended to enhance an investor’s overall understanding of year-to-year operating results and provide an indication of Exelon’s baseline operating performance excluding items that are considered by management to be not directly related to the ongoing operations of the business. In addition, this information is among the primary indicators management uses as a basis for evaluating performance, allocating resources, setting incentive
compensation targets, and planning and forecasting of future periods. Adjusted (non-GAAP) operating earnings is not a presentation defined under GAAP and may not be comparable to other companies’ presentations or deemed more useful than the GAAP information provided elsewhere in this report.
The following tables provide a reconciliation between netNet income attributable to common shareholders from continuing operations as determined in accordance with GAAP and adjustedAdjusted (non-GAAP) operating earnings for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 2021.2022:
| | | | | | | | | | | | | | | | | | | | | | | |
| | | | | | | |
| Three Months Ended June 30, |
| 2022 | | 2021 |
| (In millions, except per share data) | | | Earnings per
Diluted Share | | | | Earnings per
Diluted Share |
| Net Income Attributable to Common Shareholders from Continuing Operations | $ | 465 | | | $ | 0.47 | | | $ | 326 | | | $ | 0.33 | |
| Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $1) | — | | | — | | | 3 | | | — | |
| Cost Management Program (net of taxes of $0) | — | | | — | | | 1 | | | — | |
COVID-19 Direct Costs (net of taxes of $1)(a) | — | | | — | | | 4 | | | — | |
Acquisition Related Costs (net of taxes of $1)(b) | — | | | — | | | 2 | | | — | |
ERP System Implementation Costs (net of taxes $1)(c) | — | | | — | | | 2 | | | — | |
Separation Costs (net of taxes of $4 and $6, respectively)(d) | 10 | | | 0.01 | | | 10 | | | 0.01 | |
Income Tax-Related Adjustments (entire amount represents tax expense)(e) | (43) | | | (0.04) | | | — | | | — | |
| Adjusted (non-GAAP) Operating Earnings | $ | 433 | | | $ | 0.44 | | | $ | 348 | | | $ | 0.36 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| Six Months Ended June 30, |
| 2022 | | 2021 |
| (In millions, except per share data) | | | Earnings per
Diluted Share | | | | Earnings per
Diluted Share |
| Net Income Attributable to Common Shareholders from Continuing Operations | $ | 946 | | | $ | 0.96 | | | $ | 851 | | | $ | 0.87 | |
| Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $1) | — | | | — | | | 3 | | | — | |
| Cost Program Management (net of taxes of $0) | — | | | — | | | 1 | | | — | |
COVID-19 Direct Costs (net of taxes of $3) (a) | — | | | — | | | 5 | | | 0.01 | |
Acquisition Related Costs (net of taxes of $3)(b) | — | | | — | | | 7 | | | 0.01 | |
ERP System Implementation Costs (net of taxes of $0 and $1, respectively)(c) | 1 | | | — | | | 7 | | | 0.01 | |
Separation Costs (net of taxes of $11 and $6, respectively)(d) | 27 | | | 0.03 | | | 15 | | | 0.02 | |
Income Tax-Related Adjustments (entire amount represents tax expense)(f) | 92 | | | 0.09 | | | (2) | | | — | |
| Adjusted (non-GAAP) Operating Earnings | $ | 1,065 | | | $ | 1.08 | | | $ | 887 | | | $ | 0.91 | |
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended March 31, |
| 2023 | | 2022 |
| (In millions, except per share data) | | | Earnings per
Diluted Share | | | | Earnings per
Diluted Share |
| Net Income Attributable to Common Shareholders from Continuing Operations | $ | 669 | | | $ | 0.67 | | | $ | 481 | | | $ | 0.49 | |
| Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $0) | (1) | | | — | | | — | | | — | |
| Change in Environmental Liabilities (net of taxes of $7) | 18 | | | 0.02 | | | — | | | — | |
ERP System Implementation Costs (net of taxes of $0)(a) | — | | | — | | | 1 | | | — | |
| | | | | | | |
| | | | | | | |
| | | | | | | |
| Change in FERC Audit Liability (net of taxes of $4) | 11 | | | 0.01 | | | — | | | — | |
| | | | | | | |
Separation Costs (net of taxes of $0 and $7, respectively)(b) | (1) | | | — | | | 17 | | | 0.02 | |
Income Tax-Related Adjustments (entire amount represents tax expense)(c) | — | | | — | | | 134 | | | 0.14 | |
| Adjusted (non-GAAP) Operating Earnings | $ | 696 | | | $ | 0.70 | | | $ | 634 | | | $ | 0.64 | |
__________
Note:
Amounts may not sum due to rounding.
Unless otherwise noted, the income tax impact of each reconciling item between GAAP Net Income from Continuing Operations and Adjusted (non-GAAP) Operating Earnings is based on the marginal statutory federal and state income tax rates for each Registrant, taking into account whether the income or expense item is taxable or deductible, respectively, in whole or in part. The marginal statutory income tax rates for 20222023 and 20212022 ranged from 24.0% to 29.0%.
(a)Represents direct costs related to COVID-19 consisting primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees, which are recorded in Operating and maintenance expense.
(b)Reflects certain BSC costs related to the acquisition of Electricite de France SA's (EDF's) interest in CENG, which was completed in the third quarter of 2021, that were historically allocated to Constellation Energy Generation, LLC
(Generation) but are presented as part of continuing operations in Exelon’s results as these costs do not qualify as expenses of the discontinued operations per the accounting rules.
(c)Reflects costs related to a multi-year Enterprise Resource Program (ERP)ERP system implementation, which are recorded in Operating and maintenance expense.
(d)(b)Represents costs related to the separation primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the separation, and employee-related severance costs, which are recorded in Operating and maintenance expense.
(e)In connection with the separation, Exelon recorded a one-time impact associated with a state tax benefit.
(f)(c)In connection with the separation, Exelon recorded an income tax expense primarily due to the long-term marginal state income tax rate change, the recognition of valuation allowances against the net deferred tax assets positions for certain standalone state filing jurisdictions, and nondeductible transaction costs partially offset by a one-time impact associated with a state tax benefit.costs.
Significant 20222023 Transactions and Developments
Separation
On February 21, 2021, Exelon’s Board of Directors approved a plan to separate the Utility Registrants and Generation, creating two publicly traded companies (“the separation”). Exelon completed the separation on February 1, 2022. Constellation was newly formed and incorporated in Pennsylvania on June 15, 2021 for the purpose of separation and holds Generation. The separation represented a strategic shift that would have a major effect on Exelon’s operations and financial results. Accordingly, the separation meetsmet the criteria for discontinued operations. See Note 2 — Discontinued Operations of the Combined Notes to Consolidated Financial Statements for additional information on the separation and discontinued operations.
In connection with the separation, Exelon incurred separation (benefit)/costs impacting continuing operations of $14$(1) million and $16$24 million on a pre-tax basis for the three months ended June 30,March 31, 2023 and 2022, and 2021, respectively, and $38 million and $21 million on a pre-tax basis for the six months ended June 30, 2022 and 2021, respectively, which are recorded in Operating and maintenance expense. Total separation costs impacting continuing operations for the remainder of 20222023 are not expected to be material. These costs are excluded from Adjusted (non-GAAP) Operating Earnings. The separation costs are primarily comprised of system-related costs, third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the separation, and employee-related severance costs.
Distribution Base Rate Case Proceedings
The Utility Registrants file base rate cases with their regulatory commissions seeking increases or decreases to their electric transmission and distribution, and gas distribution rates to recover their costs and earn a fair return on their investments. The outcomes of these regulatory proceedings impact the Utility Registrants’ current and future financial statements.
The following tables show the Utility Registrants’ completed and pending distribution base rate case proceedings in 2022.2023. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information.
Completed Distribution Base Rate Case Proceedings
| | Registrant/Jurisdiction | Registrant/Jurisdiction | | Filing Date | | Service | | Requested Revenue Requirement Increase | | Approved Revenue Requirement Increase | | Approved ROE | | Approval Date | | Rate Effective Date | Registrant/Jurisdiction | | Filing Date | | Service | | Requested Revenue Requirement Increase | | Approved Revenue Requirement Increase | | Approved ROE | | Approval Date | | Rate Effective Date |
| ComEd - Illinois | ComEd - Illinois | | April 16, 2021 | | Electric | | $ | 51 | | | $ | 46 | | | 7.36 | % | | December 1, 2021 | | January 1, 2022 | ComEd - Illinois | | April 15, 2022 | | Electric | | $ | 199 | | | $ | 199 | | | 7.85 | % | | November 17, 2022 | | January 1, 2023 |
| | PECO - Pennsylvania | PECO - Pennsylvania | | March 30, 2021 | | Electric | | 246 | | | 132 | | | N/A | | November 18, 2021 | | January 1, 2022 | PECO - Pennsylvania | | March 31, 2022 | | Natural Gas | | 82 | | | 55 | | | N/A | | October 27, 2022 | | January 1, 2023 |
| BGE - Maryland | BGE - Maryland | | May 15, 2020 (amended September 11, 2020) | | Electric | | 203 | | | 140 | | | 9.50 | % | | December 16, 2020 | | January 1, 2021 | BGE - Maryland | | May 15, 2020 (amended September 11, 2020) | | Electric | | 203 | | | 140 | | | 9.50 | % | | December 16, 2020 | | January 1, 2021 |
| Natural Gas | | 108 | | | 74 | | | 9.65 | % | | | Natural Gas | | 108 | | | 74 | | | 9.65 | % | |
| Pepco - District of Columbia | | May 30, 2019 (amended June 1, 2020) | | Electric | | 136 | | | 109 | | | 9.275 | % | | June 8, 2021 | | July 1, 2021 | |
| Pepco - Maryland | Pepco - Maryland | | October 26, 2020 (amended March 31, 2021) | | Electric | | 104 | | | 52 | | | 9.55 | % | | June 28, 2021 | | June 28, 2021 | Pepco - Maryland | | October 26, 2020 (amended March 31, 2021) | | Electric | | 104 | | | 52 | | | 9.55 | % | | June 28, 2021 | | June 28, 2021 |
| DPL - Maryland | DPL - Maryland | | September 1, 2021 (amended December 23, 2021) | | Electric | | 27 | | | 13 | | | 9.60 | % | | March 2, 2022 | | March 2, 2022 | DPL - Maryland | | May 19, 2022 | | Electric | | 38 | | | 29 | | | 9.60 | % | | December 14, 2022 | | January 1, 2023 |
| ACE - New Jersey | | December 9, 2020 (amended February 26, 2021) | | Electric | | 67 | | | 41 | | | 9.60 | % | | July 14, 2021 | | January 1, 2022 | |
|
Pending Distribution Base Rate Case Proceedings
| | Registrant/Jurisdiction | Registrant/Jurisdiction | | Filing Date | | Service | | Requested Revenue Requirement Increase | | Requested ROE | | Expected Approval Timing | Registrant/Jurisdiction | | Filing Date | | Service | | Requested Revenue Requirement Increase | | Requested ROE | | Expected Approval Timing |
| ComEd - Illinois | ComEd - Illinois | | April 15, 2022 | | Electric | | $ | 199 | | | 7.85 | % | | Fourth quarter of 2022 | ComEd - Illinois | | January 17, 2023 | | Electric | | $ | 1,472 | | | 10.50% to 10.65% | | Fourth quarter of 2023 |
| | PECO - Pennsylvania | | March 31, 2022 | | Natural Gas | | 82 | | | 10.95 | % | | Fourth quarter of 2022 | |
| | ComEd - Illinois | | ComEd - Illinois | | April 21, 2023 | | Electric | | 247 | | | 8.91 | % | | Fourth quarter of 2023 |
| BGE - Maryland | | BGE - Maryland | | February 17, 2023 | | Electric | | 313 | | | 10.40 | % | | Fourth quarter of 2023 |
| Natural Gas | 289 | | | 10.40 | % | |
| Pepco - District of Columbia | | Pepco - District of Columbia | | April 13, 2023 | | Electric | | 191 | | | 10.50 | % | | First quarter of 2024 |
| DPL - Delaware | DPL - Delaware | | January 14, 2022 (amended February 28, 2022) | | Natural Gas | | 15 | | | 10.30 | % | | First quarter of 2023 | DPL - Delaware | | December 15, 2022 (amended February 28, 2023) | | Electric | | 48 | | | 10.50 | % | | Second quarter of 2024 |
| DPL - Maryland | | May 19, 2022 | | Electric | | 38 | | | 10.25 | % | | Fourth quarter of 2022 | |
| ACE - New Jersey | | ACE - New Jersey | | February 15, 2023 | | Electric | | 105 | | | 10.50 | % | | First quarter of 2024 |
Transmission Formula Rates
For 2022,2023, the following total increases/(decreases) were included in the Utility Registrants'BGE's annual electric transmission formula rate updates. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Registrant | | Initial Revenue Requirement Increase | | Annual Reconciliation (Decrease) Increase | | Total Revenue Requirement Increase | | Allowed Return on Rate Base | | Allowed ROE |
| ComEd | | $ | 24 | | | $ | (24) | | | $ | — | | | 8.11 | % | | 11.50 | % |
| PECO | | 23 | | | 16 | | | 39 | | | 7.30 | % | | 10.35 | % |
| BGE | | 25 | | | (4) | | | 16 | | | 7.30 | % | | 10.50 | % |
| Pepco | | 16 | | | 15 | | | 31 | | | 7.60 | % | | 10.50 | % |
| DPL | | 9 | | | 2 | | | 11 | | | 7.09 | % | | 10.50 | % |
| ACE | | 21 | | | 13 | | | 34 | | | 7.18 | % | | 10.50 | % |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Registrant | | Initial Revenue Requirement Increase | | Annual Reconciliation Decrease | | Total Revenue Requirement Increase | | Allowed Return on Rate Base | | Allowed ROE |
| | | | | | | | | | |
| | | | | | | | | | |
| BGE | | $ | 19 | | | $ | (12) | | | $ | 4 | | | 7.34 | % | | 10.50 | % |
| | | | | | | | | | |
| | | | | | | | | | |
| | | | | | | | | | |
Pennsylvania Corporate Income Tax Rate Change
On July 8, 2022, Pennsylvania enacted House Bill 1342, which will permanently reduce the corporate income tax rate from 9.99%The Utility Registrants are subject to 4.99%. The tax rate will be reduced to 8.99% for the 2023 tax year. Startingperiodic audits and investigations by FERC. FERC’s Division of Audits and Accounting initiated a nonpublic audit of ComEd in May 2021 evaluating ComEd’s compliance with the 2024 tax year, the rate is reduced by 0.5% annually until it reaches 4.99% in 2031. As a result(1) approved terms, rates and conditions of its federally regulated service; (2) accounting requirements of the rate change, inUniform System of Accounts; (3) reporting requirements of the third quarterFERC Form 1; and (4) the requirements for record retention. The audit covered the period from January 1, 2017 through August 31, 2022. On January 17 and February 21, 2023, ComEd was provided with information on a series of 2022,potential findings, including concerning ComEd's methodology regarding the allocation of certain overhead costs to capital under FERC regulations. As of March 31, 2023, ComEd has continued discussions with FERC staff and determined that a loss is probable and has recorded a liability that reflects management's best estimate. The final outcome and resolution of the findings or of the audit itself cannot be predicted and the results, while not reasonably estimable at this time, could be material to the Exelon and PECO will record an estimated one-time decrease to deferred income taxes of $390 million with a corresponding decrease to the deferred income taxes regulatory asset of $428 million for the amounts that are expected to be settled through future customer rates and an increase to income tax expense of $38 million (net of federal taxes), which will be excluded from Adjusted (non-GAAP) Operating Earnings.ComEd financial statements. See Note 73 — Income TaxesRegulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information.
Other Key Business Drivers and Management Strategies
The following discussion of other key business drivers and management strategies includes current developments of previously disclosed matters and new issues arising during the period that may impact future financial statements. This section should be read in conjunction with ITEM 1. Business in the 20212022 Form 10-K,, ITEM 7. Management's Discussion and Analysis of Financial Condition and Results of Operations — Other Key Business Drivers and Management Strategies in the 2021 Recast2022 Form 10-K, and Note 12 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements in this report for additional information on various environmental matters.
Legislative and Regulatory Developments
City of Chicago Franchise Agreement
The current ComEd Franchise Agreement with the City of Chicago (the City) has been in force since 1992. The Franchise Agreement grants rights to use the public right of way to install, maintain, and operate the wires, poles, and other infrastructure required to deliver electricity to residents and businesses across the City. The Franchise Agreement became terminable on one year notice as of December 31, 2020. It now continues in effect indefinitely unless and until either party issues a notice of termination, effective one year later, or it is replaced by mutual agreement with a new franchise agreement between ComEd and the City. If either party terminates and no new agreement is reached between the parties, the parties could continue with ComEd providing electric services within the City with no franchise agreement in place. The City also has an option to terminate and purchase the ComEd system (“municipalize”), which also requires one year notice. Neither party has issued a notice of termination at this time, the City has not exercised its municipalization option, and no new agreement has become effective. Accordingly, the 1992 Franchise Agreement remains in effect at this time. In April 2021, the City invited interested parties to respond to a Request for Information (RFI) regarding the franchise for electricity delivery. Final responses to the RFI were due on July 30, 2021, however, on July 29, 2021, the City chose to extend the final submission deadline to September 30, 2021. ComEd submitted its response to the RFI by the due date. However, the City did not proceed to issue an RFP. Since that time, ComEd and the City continued to negotiate and have arrived at a proposed Chicago Franchise Agreement (CFA) and an Energy and Equity Agreement (EEA). These agreements together are intended to grant ComEd the right to continue providing electric utility services using public ways within the City of Chicago, and to create a new non-profit entity to advance energy and energy-related equity projects. On February 1, 2023, the proposed CFA and EEA were introduced to the City Council. The proposed CFA and EEA remain subject to approval by the City Council and the Exelon Board.
While Exelon and ComEd cannot predict the ultimate outcome of these processes, fundamental changes in the agreements or other adverse actions affecting ComEd’s business in the City would require changes in their business planning models and operations and could have a material adverse impact on Exelon’s and ComEd’s consolidated financial statements. If the City were to disconnect from the ComEd system, ComEd would seek full compensation for the business and its associated property taken by the City, as well as for all damages resulting to ComEd and its system. ComEd would also seek appropriate compensation for stranded costs with FERC.
Infrastructure Investment and Jobs Act
On November 15, 2021, President Biden signed the $1.2 trillion Infrastructure Investment and Jobs Act (IIJA)IIJA into law. IIJA provides for approximately $550 billion in new federal spending. Categories of funding include funding for a variety of infrastructure needs, including but not limited to: (1) power and grid reliability and resilience, (2) resilience for cybersecurity to address critical infrastructure needs, and (3) electric vehicle charging infrastructure for alternative fuel corridors. Federal agencies are in the process of developing guidelines to implement spending programs under IIJA. The time needed to develop these guidelines will vary with some limited program applications opened as early as the first quarter of 2022. The Registrants are analyzingcontinuing to analyze the legislation and considering possible opportunities to apply for funding, either directly or in potential collaborations with state and/or local agencies and key stakeholders. The Registrants cannot predict the ultimate timing and success of securing funding from programs under IIJA.
Inflation Reduction ActIn September 2022, ComEd and BGE applied for the MMG, which establishes and funds construction, improvement, or acquisition of middle mile broadband infrastructure which creates high-speed internet services. The MMG addresses inequitable broadband access by expansion and extension of the middle mile infrastructure in underserved communities. The grant process is expected to be highly competitive, and therefore, ComEd and
BGE cannot predict how many of their total applications will be approved as filed or the Inflation Reduction Act was introducedprecise timing of receiving any funds if they are awarded a grant.
In March 2023, Exelon, ComEd and PHI submitted three applications related to the Smart Grid Grants program under section 40107 of IIJA. These applications are focused on replacing existing Advanced Distribution Management Systems (ADMS) in support of distributed energy resources (DERs) and grid-edged technologies, strengthening interoperability and data architecture of systems in support of two-way power flows and accelerating advanced metering deployment in disadvantaged communities. In April 2023, ComEd, PECO BGE and PHI submitted seven applications related to the U.S. Senate.Grid Resilience Grants program under section 40101(c) of IIJA. These applications are broadly focused on improving grid resilience with an emphasis on disadvantaged communities, relief of capacity constraints and modernizing infrastructure, deployment of DER and microgrid technologies and providing improved resilience through storm hardening projects. Through its applications under section 40107 and 40101(c) of IIJA, the Registrants are requesting nearly $700 million in proposed federal funding. The bill extends tax benefits for renewable technologies like solargrant process is expected to be highly competitive, and windtherefore, the Registrants cannot predict how many of their total applications will be approved as filed, or the precise timing of receiving any funds if they are awarded a grant.
The Registrants are supporting three different Regional Clean Hydrogen Hub opportunities, covering all five states that Exelon operates in plus Washington D.C. under a program that will create networks of hydrogen producers, consumers, and it creates new tax benefits for alternativelocal connective infrastructure to accelerate the use of hydrogen as a clean energy sources like nuclearcarrier that can deliver or store energy. Applications for the three opportunities under this program were submitted in April 2023. The selection process is expected to be highly competitive, and hydrogen and it focuses on energy efficiency, electrification, and equity. However,therefore, the bill also implements a new 15% corporate minimum tax based on modified GAAP net income. Exelon estimates the bill could result in an increase in cash taxes for Exelon of approximately $300 million per year starting in 2023 if enacted as proposed. Exelon is continuing to assess the impacts of the bill on the financial statements. Exelon is working with legislators andRegistrants cannot predict how many of their total applications will be approved as filed or the outcomeprecise timing of the proposed legislation.receiving any funds if they are awarded a grant.
Critical Accounting Policies and Estimates
Management of each of the Registrants makes a number of significant estimates, assumptions, and judgments in the preparation of its financial statements. At June 30, 2022,As of March 31, 2023, the Registrants’ critical accounting policies and estimates had not changed significantly from December 31, 2021.2022. See ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS — Critical Accounting Policies and Estimates in the 2021 Recast2022 Form 10-K for further information.
Results of Operations by Registrant
Results of Operations — ComEd
| | | Three Months Ended
June 30, | | Favorable
(Unfavorable)
Variance | | Six Months Ended
June 30, | | Favorable
(Unfavorable)
Variance | | | Three Months Ended
March 31, | | (Unfavorable) Favorable Variance |
| | 2022 | | 2021 | | 2022 | | 2021 | | | | 2023 | | 2022 | |
| Operating revenues | Operating revenues | $ | 1,425 | | | $ | 1,517 | | | $ | (92) | | | $ | 3,158 | | | $ | 3,052 | | | $ | 106 | | Operating revenues | | $ | 1,667 | | | $ | 1,734 | | | $ | (67) | |
| Operating expenses | Operating expenses | | Operating expenses | | |
| Purchased power | Purchased power | 283 | | | 500 | | | 217 | | | 921 | | | 1,025 | | | 104 | | Purchased power | | 488 | | | 638 | | | 150 | |
| Operating and maintenance | Operating and maintenance | 338 | | | 323 | | | (15) | | | 689 | | | 639 | | | (50) | | Operating and maintenance | | 337 | | | 351 | | | 14 | |
| Depreciation and amortization | Depreciation and amortization | 328 | | | 296 | | | (32) | | | 649 | | | 589 | | | (60) | | Depreciation and amortization | | 338 | | | 321 | | | (17) | |
| Taxes other than income taxes | Taxes other than income taxes | 90 | | | 77 | | | (13) | | | 185 | | | 153 | | | (32) | | Taxes other than income taxes | | 93 | | | 96 | | | 3 | |
| Total operating expenses | Total operating expenses | 1,039 | | | 1,196 | | | 157 | | | 2,444 | | | 2,406 | | | (38) | | Total operating expenses | | 1,256 | | | 1,406 | | | 150 | |
| Loss on sales of assets | (2) | | | — | | | (2) | | | (2) | | | — | | | (2) | | |
| | Operating income | Operating income | 384 | | | 321 | | | 63 | | | 712 | | | 646 | | | 66 | | Operating income | | 411 | | | 328 | | | 83 | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | | | | | Other income and (deductions) | | | | | | |
| Interest expense, net | Interest expense, net | (104) | | | (98) | | | (6) | | | (204) | | | (193) | | | (11) | | Interest expense, net | | (117) | | | (100) | | | (17) | |
| Other, net | Other, net | 13 | | | 15 | | | (2) | | | 26 | | | 22 | | | 4 | | Other, net | | 18 | | | 12 | | | 6 | |
| Total other income and (deductions) | Total other income and (deductions) | (91) | | | (83) | | | (8) | | | (178) | | | (171) | | | (7) | | Total other income and (deductions) | | (99) | | | (88) | | | (11) | |
| Income before income taxes | Income before income taxes | 293 | | | 238 | | | 55 | | | 534 | | | 475 | | | 59 | | Income before income taxes | | 312 | | | 240 | | | 72 | |
| Income taxes | Income taxes | 66 | | | 46 | | | (20) | | | 119 | | | 85 | | | (34) | | Income taxes | | 71 | | | 52 | | | (19) | |
| Net income | Net income | $ | 227 | | | $ | 192 | | | $ | 35 | | | $ | 415 | | | $ | 390 | | | $ | 25 | | Net income | | $ | 241 | | | $ | 188 | | | $ | 53 | |
|
Three Months Ended June 30, 2022March 31, 2023 Compared to Three Months Ended June 30, 2021.March 31, 2022. Net income increased by $35$53 million as compared to the same period in 2021,2022, primarily due to increases in electric distribution formula rate earnings (reflecting higher allowed electric distribution ROE due to an increase in treasuryU.S. Treasury rates and the impacts of higher rate base).
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net income increased by $25 million as compared to the same period in 2021, primarily due to increases in electric distribution formula rate earnings (reflecting higher allowed electric distribution ROE due to an increase in treasury rates and the impacts of higher rate base) partially offset by the voluntary customer refundcarrying costs related to the ICC investigation of matters identified in the Deferred Prosecution Agreement. See Note 12 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for additional information.CMC regulatory assets.
The changes in Operating revenues consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 |
| Increase (Decrease) | | Increase (Decrease) |
| Distribution | $ | 65 | | | $ | 110 | |
| Transmission | 17 | | | 38 | |
| Energy efficiency | 14 | | | 20 | |
| Other | — | | | 3 | |
| | | |
| | | |
| | | |
| | | |
| 96 | | | 171 | |
| Regulatory required programs | (188) | | | (65) | |
| Total increase | $ | (92) | | | $ | 106 | |
| | | | | | | |
| | | Three Months Ended
March 31, 2023 |
| | | Increase (Decrease) |
| Distribution | | | $ | 111 | |
| Transmission | | | (12) | |
| Energy efficiency | | | 14 | |
| Other | | | 2 | |
| | | 115 | |
| Regulatory required programs | | | (182) | |
| Total decrease | | | $ | (67) | |
Revenue Decoupling. The demand for electricity is affected by weather and customer usage. Operating revenues are not impacted by abnormal weather, usage per customer, or number of customers as a result of revenue decoupling mechanisms implemented pursuant to FEJA.
Distribution Revenue. EIMA and FEJA provide for a performance-based formula rate, which requires an annual reconciliation of the revenue requirement in effect to the actual costs that the ICC determines are prudently and reasonably incurred in a given year. Electric distribution revenue varies from year to year based upon fluctuations in the underlying costs, (e.g., severe weather and storm restoration), investments being recovered, and allowed ROE. Electric distribution revenue increased for the three and six months ended June 30, 2022March 31, 2023 as compared to the same period in 2021,2022, due to higher allowed ROE due to an increase in treasuryU.S. Treasury rates, the impact of a higher rate base, and higher fully recoverable costs.
Transmission Revenue. Under a FERC-approved formula, transmission revenue varies from year to year based upon fluctuations in the underlying costs, capital investments being recovered, and the highest daily peak
load, which is updated annually in January based on the prior calendar year. Generally, increases/decreases in the highest daily peak load will result in higher/lower transmission revenue. Transmission revenue increased for the three and six months ended June 30, 2022 as compared to the same period in 2021 primarily due to the impact of higher rate base and higher fully recoverable costs.
Energy Efficiency Revenue. FEJA provides for a performance-based formula rate, which requires an annual reconciliation of the revenue requirement in effect to the actual costs that the ICC determines are prudently and reasonably incurred in a given year. Under FEJA, energy efficiency revenue varies from year to year based upon fluctuations in the underlying costs, investments being recovered, and allowed ROE. Energy efficiency revenue increased for the three and six months ended June 30, 2022March 31, 2023 as compared to the same period in 2021,2022, primarily due to increased regulatory asset amortization, which is fully recoverable.
Other Revenue primarily includes assistance provided to other utilities through mutual assistance programs. Other revenue remained relatively the sameincreased for the three and six months ended June 30, 2022March 31, 2023 as compared to the same period in 2021.2022, which primarily reflects mutual assistance revenues associated with storm restoration efforts.
Regulatory Required Programs represents revenues collected under approved riders to recover costs incurred for regulatory programs such as recoveries under the credit loss expense tariff, environmental costs associated with MGP sites, Energy Transition Assistance Charge ("ETAC"),ETAC, and costs related to electricity, ZEC, CMC, and REC procurement. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information regarding CMCs. ETAC is a retail customer surcharge collected by electric utilities operating in Illinois established by CEJA and remitted to an Illinois state agency for programs to support clean energy jobs and training. The riders are designed to provide full and current cost recovery. The costs of these programs are included in Purchased power expense, Operating and maintenance expense, Depreciation and amortization expense and Taxes other than income. Customers have the choice to purchase electricity from competitive electric generation suppliers. Customer choice programs do not impact the volume of deliveries as ComEd remains the distribution service provider for all customers and charges a regulated rate for distribution service, which is recorded in Operating revenues. For customers that choose to purchase electric generation from competitive suppliers, ComEd either acts as the billing agent or the competitive supplier separately bills its own customers, and therefore does not record Operating revenues or Purchased power expense related to the electricity. For customers that choose to purchase electric generation from ComEd, ComEd is permitted to recover the electricity, ZEC, CMC, and REC procurement costs without mark-up and therefore records equal and offsetting amounts in Operating revenues and Purchased power expense related to the electricity, ZECs, CMCs, and RECs.
See Note 5 — Segment Information of the Combined Notes to Consolidated Financial Statements for the presentation of ComEd's revenue disaggregation.
The decrease of $217 million and $104$150 million for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 2021,2022, in Purchased power expense is primarily due to the CMCs from the participating nuclear-powered generating facilities including the deferral of any associated carrying costs. This favorability is offset by a decrease in Operating revenues as part of regulatory required programs. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information regarding CMCs.
The changes in Operating and maintenance expense consisted of the following:
| | | | | | | |
| | | Three Months Ended
March 31, 2023 |
| | | Increase (Decrease) |
| | | |
| Labor, other benefits, contracting and materials | | | $ | 17 | |
| Storm-related costs | | | 1 | |
| Pension and non-pension postretirement benefits expense | | | (4) | |
| | | |
| BSC costs | | | (2) | |
| | | |
Other(a) | | | (8) | |
| | | 4 | |
Regulatory required programs(b) | | | (18) | |
| Total decrease | | | $ | (14) | |
__________
(a)For the three months ended March 31, 2023, the decrease is primarily due to the voluntary customer refund made in 2022 related to the ICC investigation of matters identified in the Deferred Prosecution Agreement. See Note 12 —
The changes in Operating and maintenance expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 |
| (Decrease) Increase | | (Decrease) Increase |
| | | |
| Storm-related costs | $ | (1) | | | $ | — | |
| Pension and non-pension postretirement benefits expense | (7) | | | (14) | |
| Labor, other benefits, contracting and materials | 9 | | | 11 | |
| | | |
| BSC costs | 9 | | | 22 | |
| | | |
Other(a) | 4 | | | 26 | |
| 14 | | | 45 | |
Regulatory required programs(b) | 1 | | | 5 | |
| Total increase | $ | 15 | | | $ | 50 | |
__________
(a)For the six months ended June 30, 2022, the increase is primarily due to the voluntary customer refund related to the ICC investigation of matters identified in the Deferred Prosecution Agreement. See Note 12 —Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for additional information related to the Deferred Prosecution Agreement.
(b)ComEd is allowed to recover from or refund to customers the difference between its annual credit loss expense and the amounts collected in rates annually through a rider mechanism.
The changes in Depreciation and amortization expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 |
| Increase | | Increase |
Depreciation and amortization(a) | $ | 19 | | | $ | 33 | |
Regulatory asset amortization(b) | 13 | | | 27 | |
| | | |
| Total increase | $ | 32 | | | $ | 60 | |
| | | | | | | |
| | | Three Months Ended
March 31, 2023 |
| | | Increase |
Depreciation and amortization(a) | | | $ | 13 | |
Regulatory asset amortization(b) | | | 4 | |
| | | |
| Total increase | | | $ | 17 | |
__________
(a)Reflects ongoing capital expenditures.expenditures and higher depreciation rates effective January 2023.
(b)Includes amortization of ComEd's energy efficiency formula rate regulatory asset.
Taxes other than income taxesInterest expense, net increased by $13 million and by $32$17 million for the three and six months ended June 30, 2022, respectively,March 31, 2023, compared to the same period in 2021,2022, primarily due to taxes related to ETAC, which is recovered through Operating revenues.an increase in interest rates and the issuance of debt during the year.
Effective income tax rates were 22.5%22.8% and 19.3%21.7% for the three months ended June 30,March 31, 2023 and 2022, and 2021, respectively, and 22.3% and 17.9% for the six months ended June 30, 2022 and 2021, respectively. See Note 7 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the effective income tax rates.
Results of Operations — PECO
| | | Three Months Ended
June 30, | | Favorable
(Unfavorable)
Variance | | Six Months Ended
June 30, | | Favorable
(Unfavorable)
Variance | | | Three Months Ended
March 31, | | Favorable (Unfavorable) Variance |
| | 2022 | | 2021 | | 2022 | | 2021 | | | | 2023 | | 2022 | |
| Operating revenues | Operating revenues | $ | 816 | | | $ | 693 | | | $ | 123 | | | $ | 1,863 | | | $ | 1,582 | | | $ | 281 | | Operating revenues | | $ | 1,112 | | | $ | 1,047 | | | $ | 65 | |
| Operating expenses | Operating expenses | | Operating expenses | | |
| Purchased power and fuel | Purchased power and fuel | 283 | | | 207 | | | (76) | | | 689 | | | 523 | | | (166) | | Purchased power and fuel | | 484 | | | 407 | | | (77) | |
| Operating and maintenance | Operating and maintenance | 215 | | | 209 | | | (6) | | | 463 | | | 443 | | | (20) | | Operating and maintenance | | 270 | | | 247 | | | (23) | |
| Depreciation and amortization | Depreciation and amortization | 93 | | | 87 | | | (6) | | | 185 | | | 173 | | | (12) | | Depreciation and amortization | | 98 | | | 92 | | | (6) | |
| Taxes other than income taxes | Taxes other than income taxes | 48 | | | 49 | | | 1 | | | 95 | | | 92 | | | (3) | | Taxes other than income taxes | | 50 | | | 47 | | | (3) | |
| Total operating expenses | Total operating expenses | 639 | | | 552 | | | (87) | | | 1,432 | | | 1,231 | | | (201) | | Total operating expenses | | 902 | | | 793 | | | (109) | |
| | Operating income | Operating income | 177 | | | 141 | | | 36 | | | 431 | | | 351 | | | 80 | | Operating income | | 210 | | | 254 | | | (44) | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | | | | | Other income and (deductions) | | | | | | |
| Interest expense, net | Interest expense, net | (43) | | | (42) | | | (1) | | | (84) | | | (80) | | | (4) | | Interest expense, net | | (48) | | | (41) | | | (7) | |
| Other, net | Other, net | 8 | | | 7 | | | 1 | | | 16 | | | 12 | | | 4 | | Other, net | | 8 | | | 7 | | | 1 | |
| Total other income and (deductions) | Total other income and (deductions) | (35) | | | (35) | | | — | | | (68) | | | (68) | | | — | | Total other income and (deductions) | | (40) | | | (34) | | | (6) | |
| Income before income taxes | Income before income taxes | 142 | | | 106 | | | 36 | | | 363 | | | 283 | | | 80 | | Income before income taxes | | 170 | | | 220 | | | (50) | |
| Income taxes | Income taxes | 9 | | | 2 | | | (7) | | | 24 | | | 12 | | | (12) | | Income taxes | | 4 | | | 14 | | | 10 | |
| | Net income | Net income | $ | 133 | | | $ | 104 | | | $ | 29 | | | $ | 339 | | | $ | 271 | | | $ | 68 | | Net income | | $ | 166 | | | $ | 206 | | | $ | (40) | |
Three Months Ended June 30, 2022 Compared to Three Months Ended June 30, 2021. Net income increased by $29 million, primarily due to increases in electric and gas distribution rates.
Six Months Ended June 30, 2022March 31, 2023 Compared to SixThree Months Ended June 30, 2021March 31, 2022. Net income increaseddecreased by $68$40 million, primarily due to increasesunfavorable weather and credit loss expense, partially offset by an increase in electric and gas distribution rates.
The changes in Operating revenues consisted of the following:
| | | Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 | | | Three Months Ended
March 31, 2023 |
| | (Decrease) Increase | | (Decrease) Increase | | | (Decrease) Increase |
| | Electric | | Gas | | Total | | Electric | | Gas | | Total | | | Electric | | Gas | | Total |
| Weather | Weather | $ | (1) | | | $ | (1) | | | $ | (2) | | | $ | (5) | | | $ | (5) | | | $ | (10) | | Weather | | $ | (25) | | | $ | (25) | | | $ | (50) | |
| Volume | Volume | (2) | | | 4 | | | 2 | | | 4 | | | 10 | | | 14 | | Volume | | (7) | | | 2 | | | (5) | |
| Pricing | Pricing | 32 | | | 6 | | | 38 | | | 65 | | | 23 | | | 88 | | Pricing | | 11 | | | 23 | | | 34 | |
| Transmission | Transmission | 3 | | | — | | | 3 | | | 8 | | | — | | | 8 | | Transmission | | (2) | | | — | | | (2) | |
| Other | Other | 6 | | | 1 | | | 7 | | | 11 | | | 4 | | | 15 | | Other | | (1) | | | 6 | | | 5 | |
| | 38 | | | 10 | | | 48 | | | 83 | | | 32 | | | 115 | | | | (24) | | | 6 | | | (18) | |
| Regulatory required programs | Regulatory required programs | 58 | | | 17 | | | 75 | | | 95 | | | 71 | | | 166 | | Regulatory required programs | | 78 | | | 5 | | | 83 | |
| Total increase | Total increase | $ | 96 | | | $ | 27 | | | $ | 123 | | | $ | 178 | | | $ | 103 | | | $ | 281 | | Total increase | | $ | 54 | | | $ | 11 | | | $ | 65 | |
Weather. The demand for electricity and natural gas is affected by weather conditions. With respect to the electric business, very warm weather in summer months and, with respect to the electric and natural gas businesses, very cold weather in winter months are referred to as “favorable weather conditions” because these weather conditions result in increased deliveries of electricity and natural gas. Conversely, mild weather reduces demand. During the three months ended June 30, 2022March 31, 2023 compared to the same period in 2021, Operating revenues related to weather remained relatively consistent. During the six months ended June 30, 2022, compared to the same period in 2021, Operating revenues related to weather decreased by the impact of unfavorable weather conditions in PECO's service territory.
Heating and cooling degree-days are quantitative indices that reflect the demand for energy needed to heat or cool a home or business. Normal weather is determined based on historical average heating and cooling degree-days for a 30-year period in PECO's service territory. The changes in heating and cooling degree-days in
PECO’s service territory for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 20212022 and normal weather consisted of the following:
| | | Three Months Ended June 30, | | | | % Change | | Three Months Ended March 31, | | | | % Change |
| PECO Service Territory | PECO Service Territory | 2022 | | 2021 | Normal | 2022 vs. 2021 | | 2022 vs. Normal | PECO Service Territory | 2023 | | 2022 | Normal | 2023 vs. 2022 | | 2023 vs. Normal |
| | Heating Degree-Days | 385 | | 404 | | 424 | | (4.7) | % | | (9.2) | % | |
| Cooling Degree-Days | 434 | | 418 | | 391 | | 3.8 | % | | 11.0 | % | |
| | | Six Months Ended June 30, | | | % Change | |
| | 2022 | | 2021 | | Normal | 2022 vs. 2021 | | 2022 vs. Normal | |
| Heating Degree-Days | Heating Degree-Days | 2,613 | | | 2,706 | | 2,840 | | (3.4) | % | | (8.0) | % | Heating Degree-Days | 1,888 | | | 2,228 | | 2,418 | | (15.3) | % | | (21.9) | % |
| Cooling Degree-Days | Cooling Degree-Days | 435 | | | 423 | | 392 | | 2.8 | % | | 11.0 | % | Cooling Degree-Days | — | | | 1 | | 1 | | (100.0) | % | | (100.0) | % |
Volume. Electric volume, exclusive of the effects of weather, for the three and six months ended June 30, 2022,March 31, 2023, compared to the same period in 2021,2022, remained relatively consistent. Natural gas volume for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 2021, increased due to retail load growth.2022, remained relatively consistent.
| | Electric Retail Deliveries to Customers (in GWhs) | Electric Retail Deliveries to Customers (in GWhs) | Three Months Ended
June 30, | | % Change | | Weather - Normal % Change(b) | | Six Months Ended June 30, | | % Change | | Weather - Normal % Change(b) | Electric Retail Deliveries to Customers (in GWhs) | | Three Months Ended March 31, | | % Change | | Weather - Normal % Change(b) |
| 2022 | | 2021 | | 2022 | | 2021 | | | 2023 | | 2022 | | % Change |
| Residential | Residential | 3,060 | | 3,116 | | (1.8) | % | | (1.1) | % | | 6,818 | | 6,883 | | (0.9) | % | | 0.1 | % | Residential | | 3,358 | 3,758 | | (10.6) | % | | (0.1) | % |
| Small commercial & industrial | Small commercial & industrial | 1,813 | | 1,758 | | 3.1 | % | | 3.0 | % | | 3,750 | | 3,639 | | 3.1 | % | | 3.2 | % | Small commercial & industrial | | 1,843 | | 1,937 | | (4.9) | % | | 0.4 | % |
| Large commercial & industrial | Large commercial & industrial | 3,416 | | 3,475 | | (1.7) | % | | (1.8) | % | | 6,748 | | 6,747 | | — | % | | — | % | Large commercial & industrial | | 3,237 | | 3,332 | | (2.9) | % | | (1.2) | % |
| Public authorities & electric railroads | Public authorities & electric railroads | 135 | | 121 | | 11.6 | % | | 11.9 | % | | 317 | | 270 | | 17.4 | % | | 17.7 | % | Public authorities & electric railroads | | 168 | | 182 | | (7.7) | % | | 9.3 | % |
Total electric retail deliveries(a) | Total electric retail deliveries(a) | 8,424 | | 8,470 | | (0.5) | % | | (0.4) | % | | 17,633 | | 17,539 | | 0.5 | % | | 1.0 | % | Total electric retail deliveries(a) | | 8,606 | | 9,209 | | (6.5) | % | | (0.2) | % |
| | | As of June 30, | | As of March 31, |
| Number of Electric Customers | Number of Electric Customers | 2022 | | 2021 | Number of Electric Customers | 2023 | | 2022 |
| Residential | Residential | 1,521,728 | | 1,513,456 | Residential | 1,529,779 | | 1,521,255 |
| Small commercial & industrial | Small commercial & industrial | 155,484 | | 154,842 | Small commercial & industrial | 155,846 | | 155,485 |
| Large commercial & industrial | Large commercial & industrial | 3,114 | | 3,108 | Large commercial & industrial | 3,118 | | 3,102 |
| Public authorities & electric railroads | Public authorities & electric railroads | 10,386 | | 10,285 | Public authorities & electric railroads | 10,401 | | 10,342 |
| Total | Total | 1,690,712 | | 1,681,691 | Total | 1,699,144 | | 1,690,184 |
__________
(a)Reflects delivery volumes from customers purchasing electricity directly from PECO and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges.
(b)Reflects the change in delivery volumes assuming normalized weather based on the historical 30-year average.
| | Natural Gas Deliveries to Customers (in mmcf) | Natural Gas Deliveries to Customers (in mmcf) | Three Months Ended
June 30, | | % Change | | Weather - Normal % Change(b) | | Six Months Ended
June 30, | | % Change | | Weather - Normal % Change(b) | Natural Gas Deliveries to Customers (in mmcf) | | Three Months Ended
March 31, | | % Change | | Weather - Normal % Change(b) |
| 2022 | | 2021 | | 2022 | | 2021 | | | 2023 | | 2022 | | % Change |
| Residential | Residential | 5,206 | | 5,027 | | 3.6 | % | | 4.9 | % | | 26,043 | | 25,701 | | 1.3 | % | | 4.4 | % | Residential | | 17,190 | 20,837 | | (17.5) | % | | (2.4) | % |
| Small commercial & industrial | Small commercial & industrial | 3,638 | | 3,121 | | 16.6 | % | | 17.2 | % | | 14,184 | | 13,291 | | 6.7 | % | | 8.4 | % | Small commercial & industrial | | 8,699 | | 10,546 | | (17.5) | % | | (3.4) | % |
| Large commercial & industrial | Large commercial & industrial | 4 | | 2 | | 100.0 | % | | 12.6 | % | | 14 | | 9 | | 55.6 | % | | 11.4 | % | Large commercial & industrial | | 29 | | 10 | | 190.0 | % | | 21.7 | % |
| Transportation | Transportation | 5,707 | | 5,468 | | 4.4 | % | | 5.7 | % | | 13,346 | | 13,118 | | 1.7 | % | | 2.7 | % | Transportation | | 7,014 | | 7,639 | | (8.2) | % | | (5.4) | % |
Total natural gas retail deliveries(a) | Total natural gas retail deliveries(a) | 14,555 | | 13,618 | | 6.9 | % | | 8.0 | % | | 53,587 | | 52,119 | | 2.8 | % | | 5.0 | % | Total natural gas retail deliveries(a) | | 32,932 | | 39,032 | | (15.6) | % | | (3.2) | % |
| | | | As of June 30, | | As of March 31, |
| Number of Natural Gas Customers | Number of Natural Gas Customers | 2022 | | 2021 | Number of Natural Gas Customers | 2023 | | 2022 |
| Residential | Residential | 499,678 | | 494,895 | Residential | 504,181 | | 499,188 |
| Small commercial & industrial | Small commercial & industrial | 44,726 | | 44,450 | Small commercial & industrial | 45,003 | | 44,959 |
| Large commercial & industrial | Large commercial & industrial | 10 | | 6 | Large commercial & industrial | 9 | | 5 |
| Transportation | Transportation | 659 | | 677 | Transportation | 650 | | 664 |
| Total | Total | 545,073 | | 540,028 | Total | 549,843 | | 544,816 |
__________
(a)Reflects delivery volumes from customers purchasing natural gas directly from PECO and customers purchasing natural gas from a competitive natural gas supplier as all customers are assessed distribution charges.
(b)Reflects the change in delivery volumes assuming normalized weather based on the historical 30-year average.
Pricing for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 20212022 increased primarily due to increasesan increase in electric and gas distribution rates charged to customers.
Transmission Revenue. Under a FERC approvedFERC-approved formula, transmission revenue varies from year to year based upon fluctuations in the underlying costs and capital investments being recovered.
Other revenue primarily includes revenue related to late payment charges. Other revenue for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 2021 increased primarily due to revenue related to late payment charges.2022 remained relatively consistent.
Regulatory Required Programs represents revenues collected under approved riders to recover costs incurred for regulatory programs such as energy efficiency, PGC, and the GSA. The riders are designed to provide full and current cost recovery as well as a return. The costs of these programs are included in Purchased power and fuel expense, Operating and maintenance expense, Depreciation and amortization expense, and Income taxes. Customers have the choice to purchase electricity and natural gas from competitive electric generation and natural gas suppliers. Customer choice programs do not impact the volume of deliveries as PECO remains the distribution service provider for all customers and charges a regulated rate for distribution service, which is recorded in Operating revenues. For customers that choose to purchase electric generation or natural gas from competitive suppliers, PECO either acts as the billing agent or the competitive supplier separately bills its own customers and therefore PECO does not record Operating revenues or Purchased power and fuel expense related to the electricity and/or natural gas. For customers that choose to purchase electric generation or natural gas from PECO, PECO is permitted to recover the electricity, natural gas, and REC procurement costs without mark-up and therefore records equal and offsetting amounts in Operating revenues and Purchased power and fuel expense related to the electricity, natural gas, and RECs.
See Note 5 — Segment Information of the Combined Notes to Consolidated Financial Statements for the presentation of PECO's revenue disaggregation.
The increase of $76 million and $166$77 million for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 2021, respectively,2022, in Purchased power and fuel expense is offset in Operating revenues as part of regulatory required programs.
The changes in Operating and maintenance expense consisted of the following:
| | | | | | | | | |
| | | Three Months Ended
March 31, 2023 |
| | | Increase (Decrease) |
| Labor, other benefits, contracting and materials | | | $ | 14 | |
| Credit loss expense | | | 10 | |
| BSC costs | | | 2 | |
| Pension and non-pension postretirement benefit expense | | | (2) | |
| Storm-related costs | | | (4) | |
| Other | | | (3) | |
| | | 17 | |
| Regulatory required programs | | | 6 | |
| Total increase | | | $ | 23 | |
The changes in Depreciation and amortization expense consisted of the following:
| | | | | | | | | |
| | | Three Months Ended
March 31, 2023 |
| | | Increase (Decrease) |
Depreciation and amortization(a) | | | $ | 7 | |
| Regulatory asset amortization | | | (1) | |
| | | |
| Total increase | | | $ | 6 | |
__________
(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.
The changes in Operating and maintenance expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 |
| Increase (Decrease) | | Increase (Decrease) |
| BSC costs | $ | 7 | | | $ | 16 | |
| Credit loss expense | 1 | | | 5 | |
| Storm-related costs | 1 | | | 3 | |
| Pension and non-pension post retirement benefit expense | (3) | | | (4) | |
| Labor, other benefits, contracting and materials | (6) | | | (8) | |
| Other | 4 | | | 3 | |
| 4 | | | 15 | |
| Regulatory required programs | 2 | | | 5 | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| | | |
| Total increase | $ | 6 | | | $ | 20 | |
The changes in Depreciation and amortization expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended June 30, 2022 | | Six Months Ended
June 30, 2022 |
| Increase | | Increase |
Depreciation and amortization(a) | $ | 6 | | | $ | 12 | |
| Regulatory asset amortization | — | | | — | |
| | | |
| Total increase | $ | 6 | | | $ | 12 | |
__________
(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.
Interest expense, net increased $1 million and $4$7 million for the three and six months ended June 30, 2022March 31, 2023, compared to the same period in 2021,2022, primarily due to the issuance of debt in 20212022 and 2022.increases in interest rates.
Effective income tax rates were 6.3%2.4% and 1.9%6.4% for the three months ended June 30,March 31, 2023 and 2022, and 2021 respectively, and 6.6% and 4.2% for the for the six months ended June 30, 2022 and 2021, respectively. See Note 7 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the effective income tax rates.
Results of Operations — BGE
| | | Three Months Ended
June 30, | | Favorable
(Unfavorable)
Variance | | Six Months Ended
June 30, | | Favorable
(Unfavorable)
Variance | | | | Three Months Ended
March 31, | | Favorable (Unfavorable) Variance |
| | 2022 | | 2021 | | 2022 | | 2021 | | | | | 2023 | | 2022 | |
| Operating revenues | Operating revenues | $ | 786 | | | $ | 682 | | | $ | 104 | | | $ | 1,940 | | | $ | 1,656 | | | $ | 284 | | Operating revenues | | | $ | 1,257 | | | $ | 1,154 | | | $ | 103 | |
| Operating expenses | Operating expenses | | Operating expenses | | |
| Purchased power and fuel | Purchased power and fuel | 289 | | | 219 | | | (70) | | | 743 | | | 550 | | | (193) | | Purchased power and fuel | | | 492 | | | 454 | | | (38) | |
| Operating and maintenance | Operating and maintenance | 205 | | | 193 | | | (12) | | | 423 | | | 390 | | | (33) | | Operating and maintenance | | | 222 | | | 218 | | | (4) | |
| Depreciation and amortization | Depreciation and amortization | 152 | | | 141 | | | (11) | | | 322 | | | 293 | | | (29) | | Depreciation and amortization | | | 167 | | | 171 | | | 4 | |
| Taxes other than income taxes | Taxes other than income taxes | 71 | | | 67 | | | (4) | | | 148 | | | 139 | | | (9) | | Taxes other than income taxes | | | 83 | | | 76 | | | (7) | |
| Total operating expenses | Total operating expenses | 717 | | | 620 | | | (97) | | | 1,636 | | | 1,372 | | | (264) | | Total operating expenses | | | 964 | | | 919 | | | (45) | |
| | Operating income | Operating income | 69 | | | 62 | | | 7 | | | 304 | | | 284 | | | 20 | | Operating income | | | 293 | | | 235 | | | 58 | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | | | | | Other income and (deductions) | | | | | | | |
| Interest expense, net | Interest expense, net | (36) | | | (34) | | | (2) | | | (71) | | | (67) | | | (4) | | Interest expense, net | | | (44) | | | (35) | | | (9) | |
| Other, net | Other, net | 5 | | | 9 | | | (4) | | | 11 | | | 16 | | | (5) | | Other, net | | | 3 | | | 7 | | | (4) | |
| Total other income and (deductions) | Total other income and (deductions) | (31) | | | (25) | | | (6) | | | (60) | | | (51) | | | (9) | | Total other income and (deductions) | | | (41) | | | (28) | | | (13) | |
| Income before income taxes | Income before income taxes | 38 | | | 37 | | | 1 | | | 244 | | | 233 | | | 11 | | Income before income taxes | | | 252 | | | 207 | | | 45 | |
| Income taxes | Income taxes | 1 | | | (8) | | | (9) | | | 10 | | | (21) | | | (31) | | Income taxes | | | 52 | | | 9 | | | (43) | |
| Net income | Net income | $ | 37 | | | $ | 45 | | | $ | (8) | | | $ | 234 | | | $ | 254 | | | $ | (20) | | Net income | | | $ | 200 | | | $ | 198 | | | $ | 2 | |
|
Three Months Ended June 30, 2022March 31, 2023 Compared to Three Months Ended June 30, 2021.March 31, 2022. Net income decreased $8increased $2 million primarily due to an increase in depreciation expense, partially offset bya favorable impacts of the multi-year plans. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information on the three-year electric and natural gas distribution multi-year plans.
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net income decreased $20 million primarily due toplans, partially offset by an increase in depreciation expense and credit loss expense, partially offset by favorable impacts of the multi-year plans.interest expense. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information on the three-year electric and natural gas distribution multi-year plans.
The changes in Operating revenues consisted of the following:
| | | Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 | | | | Three Months Ended
March 31, 2023 |
| | Increase | | Increase | | | | Increase |
| | Electric | | Gas | | Total | | Electric | | Gas | | Total | | | | Electric | | Gas | | Total |
| Distribution | Distribution | $ | 17 | | | $ | 5 | | | $ | 22 | | | $ | 31 | | | $ | 15 | | | $ | 46 | | Distribution | | | $ | 26 | | | $ | 23 | | | $ | 49 | |
| Transmission | Transmission | 2 | | | — | | | 2 | | | 7 | | | — | | | 7 | | Transmission | | | 18 | | | — | | | 18 | |
| Other | Other | 3 | | | 2 | | | 5 | | | 10 | | | 5 | | | 15 | | Other | | | — | | | 1 | | | 1 | |
| | 22 | | | 7 | | | 29 | | | 48 | | | 20 | | | 68 | | | | | 44 | | | 24 | | | 68 | |
| Regulatory required programs | Regulatory required programs | 50 | | | 25 | | | 75 | | | 128 | | | 88 | | | 216 | | Regulatory required programs | | | 34 | | | 1 | | | 35 | |
| Total increase | Total increase | $ | 72 | | | $ | 32 | | | $ | 104 | | | $ | 176 | | | $ | 108 | | | $ | 284 | | Total increase | | | $ | 78 | | | $ | 25 | | | $ | 103 | |
Revenue Decoupling. The demand for electricity and natural gas is affected by weather and customer usage. However, Operating revenues are not impacted by abnormal weather or usage per customer as a result of a monthly rate adjustment that provides for fixed distribution revenue per customer by customer class. While Operating revenues are not impacted by abnormal weather or usage per customer, they are impacted by changes in the number of customers.
| | | | | | | | | | | |
| | As of March 31, |
| Number of Electric Customers | 2023 | | 2022 |
| Residential | 1,207,486 | | | 1,199,272 | |
| Small commercial & industrial | 115,658 | | | 115,363 | |
| Large commercial & industrial | 12,911 | | | 12,674 | |
| Public authorities & electric railroads | 266 | | | 268 | |
| Total | 1,336,321 | | | 1,327,577 | |
| | | | | | | | | | | |
| | As of June 30, |
| Number of Electric Customers | 2022 | | 2021 |
| Residential | 1,200,397 | | | 1,192,135 | |
| Small commercial & industrial | 115,769 | | | 114,682 | |
| Large commercial & industrial | 12,721 | | | 12,528 | |
| Public authorities & electric railroads | 267 | | | 267 | |
| Total | 1,329,154 | | | 1,319,612 | |
| | | As of June 30, | | As of March 31, |
| Number of Natural Gas Customers | Number of Natural Gas Customers | 2022 | | 2021 | Number of Natural Gas Customers | 2023 | | 2022 |
| Residential | Residential | 653,409 | | | 647,534 | | Residential | 656,583 | | | 653,397 | |
| Small commercial & industrial | Small commercial & industrial | 38,227 | | | 38,223 | | Small commercial & industrial | 38,260 | | | 38,356 | |
| Large commercial & industrial | Large commercial & industrial | 6,211 | | | 6,132 | | Large commercial & industrial | 6,261 | | | 6,193 | |
| | Total | Total | 697,847 | | | 691,889 | | Total | 701,104 | | | 697,946 | |
Distribution Revenue increased for the three and six months ended June 30, 2022,March 31, 2023, compared to the same period in 2021,2022, due to favorable impacts of the multi-year plans.
Transmission Revenue. Under a FERC-approved formula, transmission revenue varies from year to year based upon fluctuations in the underlying costs and capital investments being recovered. Transmission revenue increased for the three and six months ended June 30, 2022,March 31, 2023, compared to the same period in 2021,2022, primarily due to increases in underlying costs and capital investments.
Other Revenueincludes revenue related to late payment, charges, mutual assistance, off-system sales, and service application fees. Other revenue increased for the three and six months ended June 30, 2022, compared to the same period in 2021, primarily due to an increase in late fees charged to customers.
Regulatory Required Programs represent revenues collected under approved riders to recover costs incurred for regulatory programs such as conservation, demand response, STRIDE, and the POLR mechanism. The riders are designed to provide full and current cost recovery, as well as a return in certain instances. The costs of these programs are included in Purchased power and fuel expense, Operating and maintenance expense, Depreciation and amortization expense, and Taxes other than income taxes. Customers have the choice to purchase electricity and natural gas from competitive electric generation and natural gas suppliers. Customer choice programs do not impact the volume of deliveries as BGE remains the distribution service provider for all customers and charges a regulated rate for distribution service, which is recorded in Operating revenues. For customers that choose to purchase electric generation or natural gas from competitive suppliers, BGE acts as the billing agent and therefore does not record Operating revenues or Purchased power and fuel expense related to the electricity and/or natural gas. For customers that choose to purchase electric generation or natural gas from BGE, BGE is permitted to recover the electricity and natural gas procurement costs from customers and therefore records the amounts related to the electricity and/or natural gas in Operating revenues and Purchased power and fuel expense. BGE recovers electricity and natural gas procurement costs from customers with a slight mark-up.
See Note 5 — Segment Information of the Combined Notes to Consolidated Financial Statements for the presentation of BGE's revenue disaggregation.
The increase of $70 million and $193$38 million for thethe three and six months ended June 30, 2022March 31, 2023 compared to the same period in 2021,2022, in Purchased power and fuel expense is fully offset in Operating revenues as part of regulatory required programs.
The changes in Operating and maintenance expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 |
| | Increase (Decrease) | | Increase (Decrease) |
| Labor, other benefits, contracting, and materials | $ | 5 | | | $ | 7 | |
| Storm-related costs | (2) | | | (1) | |
| Pension and non-pension postretirement benefits expense | (3) | | | (6) | |
| BSC costs | 6 | | | 14 | |
| Credit loss expense | — | | | 14 | |
| Other | 5 | | | 2 | |
| 11 | | | 30 | |
| Regulatory required programs | 1 | | | 3 | |
| | | |
| Total increase | $ | 12 | | | $ | 33 | |
| | | |
| | | |
| | | |
| | | | | | | | | |
| | | Three Months Ended
March 31, 2023 |
| | | Increase (Decrease) |
| Labor, other benefits, contracting, and materials | | | $ | 8 | |
| Storm-related costs | | | (5) | |
| Pension and non-pension postretirement benefits expense | | | 1 | |
| BSC costs | | | 3 | |
| | | |
| | | |
| Other | | | (3) | |
| | | 4 | |
| Regulatory required programs | | | — | |
| | | |
| Total increase | | | $ | 4 | |
| | | |
| | | |
| | | |
The changes in Depreciation and amortization expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 |
| Increase | | Increase |
Depreciation and amortization(a) | $ | 9 | | | $ | 19 | |
| Regulatory required programs | 1 | | | 8 | |
| Regulatory asset amortization | 1 | | | 2 | |
| | | |
| Total increase | $ | 11 | | | $ | 29 | |
| | | | | | | | | |
| | | Three Months Ended
March 31, 2023 |
| | | Increase (Decrease) |
Depreciation and amortization(a) | | | $ | 7 | |
| Regulatory required programs | | | (9) | |
| Regulatory asset amortization | | | (2) | |
| | | |
| Total decrease | | | $ | (4) | |
__________
(a)Depreciation and amortizatiaonmortization increased primarily due to ongoing capital expenditures.
Taxes other than income taxes
Interest expense, net increased by $4 million and $9 million for the three and six months ended June 30, 2022, respectively,March 31, 2023, compared to the same period in 2021,2022, primarily due to increased property taxes.an increase in interest rates and the issuance of debt in Q2 2022.
Effective income tax rates were 2.6%20.6% and (21.6)%4.3% for the three months ended June 30,March 31, 2023 and 2022, and 2021, respectively, and 4.1% and (9.0)% for the six months ended June 30, 2022 and 2021, respectively. The change is primarily due to decreasesa decrease in the multi-year plans' accelerated income tax benefits in 20222023 as compared to 2021.2022. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information on the three-year electric and natural gas distribution multi-year plans and Note 7 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the effective income tax rates.
Results of Operations — PHI
PHI’s Results of Operations include the results of its three reportable segments, Pepco, DPL, and ACE. PHI also has a business services subsidiary, PHISCO, which provides a variety of support services, and the costs are directly charged or allocated to the applicable subsidiaries. Additionally, the results of PHI’s corporate operations include interest costs from various financing activities. All material intercompany accounts and transactions have been eliminated in consolidation. The following table sets forth PHI's GAAP consolidated Net income, by Registrant, for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 2021.2022. See the Results of Operations for Pepco, DPL, and ACE for additional information.
| | | Three Months Ended
June 30, | | (Unfavorable) Variance | | Six Months Ended June 30, | | (Unfavorable) Favorable Variance | | Three Months Ended
March 31, | | Favorable (Unfavorable) Variance | |
| | 2022 | | 2021 | | 2022 | | 2021 | | | 2023 | | 2022 | | |
| PHI | PHI | $ | 100 | | | $ | 141 | | | $ | (41) | | | $ | 230 | | | $ | 269 | | | $ | (39) | | PHI | $ | 155 | | | $ | 130 | | | $ | 25 | | |
| Pepco | Pepco | 70 | | | 75 | | | (5) | | | 116 | | | 134 | | | (18) | | Pepco | 65 | | | 46 | | | 19 | | |
| DPL | DPL | 21 | | | 30 | | | (9) | | | 77 | | | 86 | | | (9) | | DPL | 60 | | | 56 | | | 4 | | |
| ACE | ACE | 11 | | | 37 | | | (26) | | | 37 | | | 51 | | | (14) | | ACE | 33 | | | 26 | | | 7 | | |
Other(a) | Other(a) | (2) | | | (1) | | | (1) | | | — | | | (2) | | | 2 | | Other(a) | (3) | | | 2 | | | (5) | | |
__________
(a)Primarily includes eliminating and consolidating adjustments, PHI's corporate operations, shared service entities, and other financing and investinginvestment activities.
Three Months Ended June 30, 2022March 31, 2023 Compared to Three Months Ended June 30, 2021.March 31, 2022. Net Income decreasedincreased by $41$25 million primarily due to the absence of favorable weather and volume as a result of the CIP at ACE, an increase in credit loss expense at Pepco, higher contracting costs partially due to timing of maintenance projects at Pepco, depreciation and amortization expense, and the timing of excess deferred tax amortization at ACE, partially offset by favorable impacts as a result of Pepco'sPepco Maryland and DPL Maryland multi-year plans, timing of decoupling revenues in the District of Columbia, multi-year plans and higher electric distribution rates at DPL Delaware, and ACE.
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net Income decreased by $39 million primarily due to the absence of favorable weather and volume as a result of the CIP at ACE, an increase in storm costs at Pepco and DPL, credit loss expense at Pepco and DPL, higher contracting costs partially due to timing of maintenance projects at Pepco, depreciation and amortization expense, interest expense, and timing of excess deferred tax amortizationtransmission rates at Pepco and ACE, partially offset by favorable impacts as a result of Pepco's Marylandan increase in environmental liabilities at Pepco, and District of Columbia multi-year plans and higher electric distribution rateunfavorable weather conditions at DPL Delaware electric and ACE.
Results of Operations — Pepco
| | | Three Months Ended June 30, | | Favorable (Unfavorable) Variance | | Six Months Ended June 30, | | Favorable (Unfavorable) Variance | | Three Months Ended March 31, | | Favorable (Unfavorable) Variance | |
| 2022 | | 2021 | | | 2022 | | 2021 | | 2023 | | 2022 | | |
| Operating revenues | Operating revenues | $ | 581 | | | $ | 523 | | | $ | 58 | | | $ | 1,195 | | | $ | 1,076 | | | $ | 119 | | Operating revenues | $ | 710 | | | $ | 614 | | | $ | 96 | | |
| | Operating expenses | Operating expenses | | Operating expenses | | |
| Purchased power | Purchased power | 162 | | | 133 | | | (29) | | | 375 | | | 298 | | | (77) | | Purchased power | 258 | | | 213 | | | (45) | | |
| Operating and maintenance | Operating and maintenance | 128 | | | 113 | | | (15) | | | 260 | | | 221 | | | (39) | | Operating and maintenance | 150 | | | 131 | | | (19) | | |
| Depreciation and amortization | Depreciation and amortization | 105 | | | 96 | | | (9) | | | 213 | | | 199 | | | (14) | | Depreciation and amortization | 108 | | | 108 | | | — | | |
| Taxes other than income taxes | Taxes other than income taxes | 92 | | | 87 | | | (5) | | | 186 | | | 177 | | | (9) | | Taxes other than income taxes | 94 | | | 95 | | | 1 | | |
| Total operating expenses | Total operating expenses | 487 | | | 429 | | | (58) | | | 1,034 | | | 895 | | | (139) | | Total operating expenses | 610 | | | 547 | | | (63) | | |
| | Operating income | Operating income | 94 | | | 94 | | | — | | | 161 | | | 181 | | | (20) | | Operating income | 100 | | | 67 | | | 33 | | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | | | | | Other income and (deductions) | | | | | | |
| Interest expense, net | Interest expense, net | (38) | | | (35) | | | (3) | | | (74) | | | (69) | | | (5) | | Interest expense, net | (39) | | | (36) | | | (3) | | |
| Other, net | Other, net | 13 | | | 13 | | | — | | | 26 | | | 25 | | | 1 | | Other, net | 16 | | | 13 | | | 3 | | |
| Total other income and (deductions) | Total other income and (deductions) | (25) | | | (22) | | | (3) | | | (48) | | | (44) | | | (4) | | Total other income and (deductions) | (23) | | | (23) | | | — | | |
| Income before income taxes | Income before income taxes | 69 | | | 72 | | | (3) | | | 113 | | | 137 | | | (24) | | Income before income taxes | 77 | | | 44 | | | 33 | | |
| Income taxes | Income taxes | (1) | | | (3) | | | (2) | | | (3) | | | 3 | | | 6 | | Income taxes | 12 | | | (2) | | | (14) | | |
| Net income | Net income | $ | 70 | | | $ | 75 | | | $ | (5) | | | $ | 116 | | | $ | 134 | | | $ | (18) | | Net income | $ | 65 | | | $ | 46 | | | $ | 19 | | |
Three Months Ended June 30, 2022March 31, 2023 Compared to Three Months Ended June 30, 2021.March 31, 2022. Net Income decreasedincreased by $519 million primarily due to an increase in depreciation expense, credit loss expense, and higher contracting costs partially due to timing of maintenance projects, partially offset by the favorable impacts of the Maryland andmulti-year plan, timing of decoupling revenues in the District of Columbia, multi-year plans.
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021.Net income decreasedand higher transmission rates, partially offset by $18 million primarily due to an increase in depreciation expense, credit loss expense, storm costs, higher contracting costs partially due to timing of maintenance projects, and timing of excess deferred tax amortization, partially offset by the favorable impacts of the Maryland and District of Columbia multi-year plans.environmental liabilities.
The changes in Operating revenues consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended June 30, 2022 |
| Increase | | Increase |
| Distribution | $ | 20 | | | $ | 26 | |
| Transmission | 5 | | | 8 | |
| Other | 4 | | | — | |
| 29 | | | 34 | |
| Regulatory required programs | 29 | | | 85 | |
| Total increase | $ | 58 | | | $ | 119 | |
| | | | | | | |
| Three Months Ended
March 31, 2023 | | |
| Increase | | |
| Distribution | $ | 40 | | | |
| Transmission | 18 | | | |
| | | |
| 58 | | | |
| Regulatory required programs | 38 | | | |
| Total increase | $ | 96 | | | |
Revenue Decoupling. The demand for electricity is affected by weather and customer usage. However, Operating revenues from electric distribution in both Maryland and the District of Columbia are not impacted by abnormal weather or usage per customer as a result of a bill stabilization adjustment (BSA)BSA that provides for a fixed distribution charge per customer by customer class. While Operating revenues are not impacted by abnormal weather or usage per customer, they are impacted by changes in the number of customers.
| | | | | | | | | | | |
| As of March 31, |
| Number of Electric Customers | 2023 | | 2022 |
| Residential | 859,207 | | | 846,258 | |
| Small commercial & industrial | 54,089 | | | 54,509 | |
| Large commercial & industrial | 22,858 | | | 22,620 | |
| Public authorities & electric railroads | 201 | | | 184 | |
| Total | 936,355 | | | 923,571 | |
| | | | | | | | | | | |
| As of June 30, |
| Number of Electric Customers | 2022 | | 2021 |
| Residential | 850,569 | | | 837,744 | |
| Small commercial & industrial | 54,349 | | | 53,669 | |
| Large commercial & industrial | 22,771 | | | 22,579 | |
| Public authorities & electric railroads | 194 | | | 178 | |
| Total | 927,883 | | | 914,170 | |
Distribution Revenue increased for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 20212022 primarily due to favorable impacts of the Maryland multi-year plan and higher rates due to the expiration of customer offsets and timing of decoupling revenues in the District of Columbia multi-year plans.Columbia.
Transmission RevenueRevenue. Under a FERC-approved formula, transmission revenue varies from year to year based upon fluctuations in the underlying costs and capital investments being recovered. Transmission revenue increased for the three and six months ended June 30, 2022,March 31, 2023, compared to the same period in 2021,2022, primarily due to increases in capital investment and underlying costs.
Other Revenue includes rental revenue, revenue related to late payment charges, mutual assistance revenues, and recoveries of other taxes.
Regulatory Required Programs represent revenues collected under approved riders to recover costs incurred for regulatory programs such as energy efficiency programs, DC PLUG, and SOS procurement and administrative costs. The riders are designed to provide full and current cost recovery as well as a return in certain instances. The costs of these programs are included in Purchased power expense, Operating and maintenance expense, Depreciation and amortization expense, and Taxes other than income taxes. Customers have the choice to purchase electricity from competitive electric generation suppliers. Customer choice programs do not impact the volume of deliveries, as Pepco remains the distribution service provider for all customers and charges a regulated rate for distribution service, which is recorded in Operating revenues. For customers that choose to purchase electric generation from competitive suppliers, Pepco acts as the billing agent and therefore, Pepco does not record Operating revenues or Purchased power expense related to the electricity. For customers that choose to purchase electric generation from Pepco, Pepco is permitted to recover the electricity and REC procurement costs from customers and therefore records the amounts related to the electricity and RECs in Operating revenues and Purchased power expense. Pepco recovers electricity and REC procurement costs from customers with a slight mark-up.
See Note 5 — Segment Information of the Combined Notes to Consolidated Financial Statements for the presentation of Pepco's revenue disaggregation.
The increase of $29 million and $77$45 million for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 2021, respectively,2022, in Purchased power expense is fully offset in Operating revenues as part of regulatory required programs.
The changes in Operating and maintenance expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended June 30, 2022 |
| Increase (Decrease) | | Increase |
| BSC and PHISCO Costs | $ | 7 | | | $ | 11 | |
Labor, other benefits, contracting and materials(a) | 6 | | | 9 | |
| Credit loss expense | 5 | | | 9 | |
| Storm-related costs | — | | | 6 | |
| | | |
| | | |
| | | |
| Other | (5) | | | 2 | |
| 13 | | | 37 | |
| | | |
| Regulatory required programs | 2 | | | 2 | |
| Total increase | $ | 15 | | | $ | 39 | |
| | | | | | | |
| Three Months Ended
March 31, 2023 | | |
| Increase (Decrease) | | |
Labor, other benefits, contracting and materials(a) | $ | 24 | | | |
| Pension and non-pension postretirement benefits expense | 3 | | | |
| | | |
| | | |
| Storm-related costs | (5) | | | |
| Credit loss expense | (4) | | | |
| BSC and PHISCO Costs | (1) | | | |
| Other | (3) | | | |
| 14 | | | |
| | | |
| Regulatory required programs | 5 | | | |
| Total increase | $ | 19 | | | |
____________________
(a)Primarily reflects higher contracting costs partially due to timing of maintenance projects.an increase in environmental liabilities.
The changes in Depreciation and amortization expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended June 30, 2022 |
| Increase | | Increase (Decrease) |
Depreciation and amortization(a) | $ | 6 | | | $ | 11 | |
| Regulatory asset amortization | 2 | | | (3) | |
| Regulatory required programs | 1 | | | 6 | |
| Total increase | $ | 9 | | | $ | 14 | |
| | | | | | | |
| Three Months Ended
March 31, 2023 | | |
| Increase (Decrease) | | |
Depreciation and amortization(a) | $ | 3 | | | |
| Regulatory asset amortization | 4 | | | |
| Regulatory required programs | (7) | | | |
| Total increase | $ | — | | | |
__________
(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.
Effective income tax rates were (1.4)%15.6% and (4.2)(4.5)% for three months ended June 30,March 31, 2023 and 2022, and 2021, respectively, and (2.7)% and 2.2% for the six months ended June 30, 2022 and 2021, respectively. The three months ended June 30, 2022 change is primarily due to the acceleration of certain income tax benefits as a result of the Maryland and District of Columbia multi-year plans. The six months ended June 30, 2022 change is primarily due to the acceleration of certain income tax benefits as a result of the Maryland and District of Columbia multi-year plans, partially offset with the timing of excess deferred tax amortization. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statement for additional information on the three-year electric distribution multi-year plans and Note 7 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the effective income tax rates.
Results of Operations — DPL
| | | Three Months Ended June 30, | | Favorable (Unfavorable) Variance | | Six Months Ended June 30, | | Favorable (Unfavorable) Variance | | Three Months Ended March 31, | | Favorable (Unfavorable) Variance | |
| 2022 | | 2021 | | 2022 | | 2021 | | 2023 | | 2022 | | |
| Operating revenues | Operating revenues | $ | 332 | | | $ | 298 | | | $ | 34 | | | $ | 763 | | | $ | 680 | | | $ | 83 | | Operating revenues | $ | 474 | | | $ | 431 | | | $ | 43 | | |
| Operating expenses | Operating expenses | | Operating expenses | | |
| Purchased power and fuel | Purchased power and fuel | 135 | | | 108 | | | (27) | | | 324 | | | 263 | | | (61) | | Purchased power and fuel | 221 | | | 189 | | | (32) | | |
| Operating and maintenance | Operating and maintenance | 88 | | | 80 | | | (8) | | | 181 | | | 164 | | | (17) | | Operating and maintenance | 87 | | | 93 | | | 6 | | |
| Depreciation and amortization | Depreciation and amortization | 56 | | | 51 | | | (5) | | | 113 | | | 104 | | | (9) | | Depreciation and amortization | 60 | | | 57 | | | (3) | | |
| Taxes other than income taxes | Taxes other than income taxes | 17 | | | 16 | | | (1) | | | 35 | | | 33 | | | (2) | | Taxes other than income taxes | 20 | | | 18 | | | (2) | | |
| Total operating expenses | Total operating expenses | 296 | | | 255 | | | (41) | | | 653 | | | 564 | | | (89) | | Total operating expenses | 388 | | | 357 | | | (31) | | |
| | Operating income | Operating income | 36 | | | 43 | | | (7) | | | 110 | | | 116 | | | (6) | | Operating income | 86 | | | 74 | | | 12 | | |
| Other income and (deductions) | Other income and (deductions) | | | | | | | | | | | | Other income and (deductions) | | | | | | |
| Interest expense, net | Interest expense, net | (17) | | | (16) | | | (1) | | | (33) | | | (30) | | | (3) | | Interest expense, net | (17) | | | (16) | | | (1) | | |
| Other, net | Other, net | 4 | | | 4 | | | — | | | 6 | | | 6 | | | — | | Other, net | 3 | | | 2 | | | 1 | | |
| Total other income and (deductions) | Total other income and (deductions) | (13) | | | (12) | | | (1) | | | (27) | | | (24) | | | (3) | | Total other income and (deductions) | (14) | | | (14) | | | — | | |
| Income before income taxes | Income before income taxes | 23 | | | 31 | | | (8) | | | 83 | | | 92 | | | (9) | | Income before income taxes | 72 | | | 60 | | | 12 | | |
| Income taxes | Income taxes | 2 | | | 1 | | | (1) | | | 6 | | | 6 | | | — | | Income taxes | 12 | | | 4 | | | (8) | | |
| Net income | Net income | $ | 21 | | | $ | 30 | | | $ | (9) | | | $ | 77 | | | $ | 86 | | | $ | (9) | | Net income | $ | 60 | | | $ | 56 | | | $ | 4 | | |
Three Months Ended June 30, 2022March 31, 2023 Compared to Three Months Ended June 30, 2021.March 31, 2022. Net income decreased $9increased $4 million primarily due to an increase in depreciation expensefavorable impacts of the Maryland multi-year plan, higher Delaware electric and various operating expensesnatural gas distribution rates, partially offset by higherunfavorable weather conditions at Delaware electric distribution rates.
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net income decreased $9 million primarily due to an increase in credit loss expense, depreciation expense, and various operating expenses, partially offset by higher electric distribution rates.natural gas service territories.
The changes in Operating revenues consisted of the following:
| | | Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 | | Three Months Ended
March 31, 2023 | |
| | (Decrease) Increase | | (Decrease) Increase | | (Decrease) Increase | |
| | Electric | | Gas | | Total | | Electric | | Gas | | Total | | Electric | | Gas | | Total | |
| Weather | Weather | $ | (1) | | | $ | — | | | $ | (1) | | | $ | (1) | | | $ | — | | | $ | (1) | | Weather | $ | (5) | | | $ | (4) | | | $ | (9) | | |
| Volume | Volume | (1) | | | 2 | | | 1 | | | 3 | | | 3 | | | 6 | | Volume | (2) | | | (2) | | | (4) | | |
| Distribution | Distribution | 5 | | | 1 | | | 6 | | | 10 | | | 3 | | | 13 | | Distribution | 11 | | | 5 | | | 16 | | |
| Transmission | Transmission | (1) | | | — | | | (1) | | | 2 | | | — | | | 2 | | Transmission | 7 | | | — | | | 7 | | |
| | | 2 | | | 3 | | | 5 | | | 14 | | | 6 | | | 20 | | | 11 | | | (1) | | | 10 | | |
| Regulatory required programs | Regulatory required programs | 18 | | | 11 | | | 29 | | | 43 | | | 20 | | | 63 | | Regulatory required programs | 18 | | | 15 | | | 33 | | |
| Total increase | Total increase | $ | 20 | | | $ | 14 | | | $ | 34 | | | $ | 57 | | | $ | 26 | | | $ | 83 | | Total increase | $ | 29 | | | $ | 14 | | | $ | 43 | | |
Revenue Decoupling. The demand for electricity is affected by weather and customer usage. However, Operating revenues from electric distribution in Maryland are not impacted by abnormal weather or usage per customer as a result of a bill stabilization adjustment (BSA)BSA that provides for a fixed distribution charge per customer by customer class. While Operating revenues from electric distribution customers in Maryland are not impacted by abnormal weather or usage per customer, they are impacted by changes in the number of customers.
Weather. The demand for electricity and natural gas in Delaware is affected by weather conditions. With respect to the electric business, very warm weather in summer months and, with respect to the electric and natural gas businesses, very cold weather in winter months are referred to as "favorable weather conditions” because these weather conditions result in increased deliveries of electricity and natural gas. Conversely, mild weather reduces demand. During the three months ended March 31, 2023 compared to the same period in 2022, Operating revenues related to weather decreased due to unfavorable weather conditions in Delaware electric and natural gas service territories.
demand. During the three and six months ended June 30, 2022 compared to the same period in 2021, Operating revenues related to weather remained relatively consistent.
Heating and cooling degree days are quantitative indices that reflect the demand for energy needed to heat or cool a home or business. Normal weather is determined based on historical average heating and cooling degree days for a 20-year period in DPL'sthe Delaware electric service territory and a 30-year period in DPL'sthe Delaware natural gas service territory. The changes in heating and cooling degree days in DPL’sthe Delaware service territory for the three and six months ended June 30, 2022March 31, 2023 compared to same period in 20212022 and normal weather consisted of the following:
| | | | | | Three Months Ended June 30, | | % Change | | Three Months Ended March 31, | | % Change |
| Delaware Electric Service Territory | Delaware Electric Service Territory | 2022 | | 2021 | | Normal | | 2022 vs. 2021 | | 2022 vs. Normal | Delaware Electric Service Territory | 2023 | | 2022 | | Normal | | 2023 vs. 2022 | | 2023 vs. Normal |
| Heating Degree-Days | Heating Degree-Days | 441 | | | 480 | | | 471 | | | (8.1) | % | | (6.4) | % | Heating Degree-Days | 1,952 | | | 2,355 | | | 2,489 | | | (17.1) | % | | (21.6) | % |
| Cooling Degree-Days | Cooling Degree-Days | 328 | | | 361 | | | 336 | | | (9.1) | % | | (2.4) | % | Cooling Degree-Days | — | | | 3 | | | 1 | | | (100.0) | % | | (100.0) | % |
| | Six Months Ended June 30, | | % Change | |
| 2022 | | 2021 | | Normal | | 2022 vs. 2021 | | 2022 vs. Normal | |
| Heating Degree-Days | 2,796 | | | 2,838 | | | 2,951 | | | (1.5) | % | | (5.3) | % | |
| Cooling Degree-Days | 331 | | | 364 | | | 336 | | | (9.1) | % | | (1.5) | % | |
| | | | | | Three Months Ended June 30, | | % Change | | Three Months Ended March 31, | | % Change |
| Delaware Natural Gas Service Territory | Delaware Natural Gas Service Territory | 2022 | | 2021 | | Normal | | 2022 vs. 2021 | | 2022 vs. Normal | Delaware Natural Gas Service Territory | 2023 | | 2022 | | Normal | | 2023 vs. 2022 | | 2023 vs. Normal |
| Heating Degree-Days | Heating Degree-Days | 441 | | | 480 | | | 492 | | | (8.1) | % | | (10.4) | % | Heating Degree-Days | 1,952 | | | 2,355 | | | 2,497 | | | (17.1) | % | | (21.8) | % |
| | Six Months Ended June 30, | | % Change | |
| 2022 | | 2021 | | Normal | | 2022 vs. 2021 | | 2022 vs. Normal | |
| Heating Degree-Days | 2,796 | | | 2,838 | | | 2,993 | | | (1.5) | % | | (6.6) | % | |
Volume, exclusive of the effects of weather, remained relatively consistentdecreased for the three months ended June 30, 2022March 31, 2023 compared to the same period in 2021 and increased for the six months ended June 30, 2022 compared to the same period in2021 primarily due to customer growth and usage.usage, partially offset by customer growth.
| | Electric Retail Deliveries to Delaware Customers (in GWhs) | Electric Retail Deliveries to Delaware Customers (in GWhs) | Three Months Ended
June 30, | | % Change | | Weather - Normal % Change(b) | | Six Months Ended
June 30, | | % Change | | Weather - Normal % Change(b) | Electric Retail Deliveries to Delaware Customers (in GWhs) | | Three Months Ended
March 31, | | % Change | | Weather - Normal % Change(b) |
| 2022 | | 2021 | | 2022 | | 2021 | | | 2023 | | 2022 | |
| Residential | Residential | 675 | | | 703 | | | (4.0) | % | | (1.7) | % | | 1,570 | | | 1,557 | | | 0.8 | % | | 1.6 | % | Residential | | 797 | | | 895 | | | (10.9) | % | | (1.2) | % |
| Small commercial & industrial | Small commercial & industrial | 337 | | | 357 | | | (5.6) | % | | (4.8) | % | | 706 | | | 699 | | | 1.0 | % | | 1.4 | % | Small commercial & industrial | | 327 | | | 370 | | | (11.6) | % | | (7.2) | % |
| Large commercial & industrial | Large commercial & industrial | 773 | | | 810 | | | (4.6) | % | | (4.2) | % | | 1,538 | | | 1,499 | | | 2.6 | % | | 2.8 | % | Large commercial & industrial | | 719 | | | 765 | | | (6.0) | % | | (4.7) | % |
| Public authorities & electric railroads | Public authorities & electric railroads | 8 | | | 10 | | | (20.0) | % | | (19.9) | % | | 17 | | | 19 | | | (10.5) | % | | (7.9) | % | Public authorities & electric railroads | | 9 | | | 9 | | | — | % | | (6.3) | % |
Total electric retail deliveries(a) | Total electric retail deliveries(a) | 1,793 | | | 1,880 | | | (4.6) | % | | (3.5) | % | | 3,831 | | | 3,774 | | | 1.5 | % | | 2.0 | % | Total electric retail deliveries(a) | | 1,852 | | | 2,039 | | | (9.2) | % | | (3.6) | % |
| | | As of June 30, | | As of March 31, |
| Number of Total Electric Customers (Maryland and Delaware) | Number of Total Electric Customers (Maryland and Delaware) | 2022 | | 2021 | Number of Total Electric Customers (Maryland and Delaware) | 2023 | | 2022 |
| Residential | Residential | 479,728 | | | 475,061 | | Residential | 482,979 | | | 478,009 | |
| Small commercial & industrial | Small commercial & industrial | 63,574 | | | 62,880 | | Small commercial & industrial | 63,794 | | | 63,296 | |
| Large commercial & industrial | Large commercial & industrial | 1,222 | | | 1,213 | | Large commercial & industrial | 1,236 | | | 1,221 | |
| Public authorities & electric railroads | Public authorities & electric railroads | 598 | | | 607 | | Public authorities & electric railroads | 595 | | | 603 | |
| Total | Total | 545,122 | | | 539,761 | | Total | 548,604 | | | 543,129 | |
__________
(a)Reflects delivery volumes from customers purchasing electricity directly from DPL and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges.
(b)Reflects the change in delivery volumes assuming normalized weather based on the historical 20-year average.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Natural Gas Retail Deliveries to Delaware Customers (in mmcf) | | | | | | | Three Months Ended
March 31, | | % Change | | Weather - Normal % Change(b) |
| | | | | | 2023 | | 2022 | | |
| Residential | | | | | | | | | 3,581 | | | 4,453 | | | (19.6) | % | | (6.6) | % |
| Small commercial & industrial | | | | | | | | | 1,652 | | | 1,983 | | | (16.7) | % | | (1.8) | % |
| Large commercial & industrial | | | | | | | | | 414 | | | 457 | | | (9.4) | % | | (9.5) | % |
| Transportation | | | | | | | | | 1,900 | | | 2,207 | | | (13.9) | % | | (6.9) | % |
Total natural gas deliveries(a) | | | | | | | | | 7,547 | | | 9,100 | | | (17.1) | % | | (5.8) | % |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Natural Gas Retail Deliveries to Delaware Customers (in mmcf) | Three Months Ended
June 30, | | % Change | | Weather - Normal % Change(b) | | Six Months Ended
June 30, | | % Change | | Weather - Normal % Change(b) |
| 2022 | | 2021 | | | | 2022 | | 2021 | | |
| Residential | 983 | | | 713 | | | 37.9 | % | | 44.6 | % | | 5,436 | | | 5,107 | | | 6.4 | % | | 6.3 | % |
| Small commercial & industrial | 570 | | | 430 | | | 32.6 | % | | 39.2 | % | | 2,550 | | | 2,295 | | | 11.1 | % | | 12.0 | % |
| Large commercial & industrial | 402 | | | 393 | | | 2.3 | % | | 2.3 | % | | 863 | | | 853 | | | 1.2 | % | | 1.1 | % |
| Transportation | 1,444 | | | 1,470 | | | (1.8) | % | | (0.7) | % | | 3,650 | | | 3,694 | | | (1.2) | % | | (0.7) | % |
Total natural gas deliveries(a) | 3,399 | | | 3,006 | | | 13.1 | % | | 16.3 | % | | 12,499 | | | 11,949 | | | 4.6 | % | | 4.9 | % |
| | | As of June 30, | | As of March 31, |
| Number of Delaware Natural Gas Customers | Number of Delaware Natural Gas Customers | 2022 | | 2021 | Number of Delaware Natural Gas Customers | 2023 | | 2022 |
| Residential | Residential | 128,715 | | | 127,503 | | Residential | 129,791 | | | 128,695 | |
| Small commercial & industrial | Small commercial & industrial | 10,068 | | | 9,953 | | Small commercial & industrial | 10,158 | | | 10,097 | |
| Large commercial & industrial | Large commercial & industrial | 16 | | | 18 | | Large commercial & industrial | 16 | | | 17 | |
| Transportation | Transportation | 157 | | | 158 | | Transportation | 158 | | | 159 | |
| Total | Total | 138,956 | | | 137,632 | | Total | 140,123 | | | 138,968 | |
__________
(a)Reflects delivery volumes from customers purchasing natural gas directly from DPL and customers purchasing natural gas from a competitive natural gas supplier as all customers are assessed distribution charges.
(b)Reflects the change in delivery volumes assuming normalized weather based on the historical 30-year average.
Distribution Revenue increased for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 20212022 primarily due to higher electric distribution rates infavorable impacts of the Maryland multi-year plan that became effective in MarchJanuary 2023, higher natural gas distribution rates effective in August 2022, and higher Distribution System Improvement Charge (DSIC)DSIC rates in Delaware that became effective in January 2022, and higher approved electric distribution rates in Delaware that became effective in September 2021.2023.
Transmission Revenues.Revenue. Under a FERC-approved formula, transmission revenue varies from year to year based upon fluctuations in the underlying costs and capital investments being recovered. Transmission revenue remained relatively consistent forDuring the three months ended June 30, 2022March 31, 2023 compared to the same period in 2021. Transmission2022, transmission revenue increased, for the six months ended June 30, 2022 compared to the same period in 2021,primarily due to increases in underlying costs.
Other Revenue includes rental revenue, revenue related to late payment charges, mutual assistance revenues, and recoveries of other taxes.
Regulatory Required Programs represent revenues collected under approved riders to recover costs incurred for regulatory programs such as energy efficiency programs, DE Renewable Portfolio Standards, SOS procurement and administrative costs, and GCR costs. The riders are designed to provide full and current cost recovery as well as a return in certain instances. The costs of these programs are included in Purchased power and fuel expense, Operating and maintenance expense, Depreciation and amortization expense, and Taxes other than income taxes. All customers have the choice to purchase electricity from competitive electric generation suppliers; however, only certain commercial and industrial customers have the choice to purchase natural gas from competitive natural gas suppliers. Customer choice programs do not impact the volume of deliveries as DPL remains the distribution service provider for all customers and charges a regulated rate for distribution service, which is recorded in Operating revenues. For customers that choose to purchase electric generation or natural gas from competitive suppliers, DPL either acts as the billing agent or the competitive supplier separately bills its own customers, and therefore does not record Operating revenues or Purchased power and fuel expense related to the electricity and/or natural gas. For customers that choose to purchase electric generation or natural gas from DPL, DPL is permitted to recover the electricity, natural gas, and REC procurement costs from customers and therefore records the amounts related to the electricity, natural gas, and RECs in Operating revenues and Purchased power and fuel expense. DPL recovers electricity and REC procurement costs from customers with a slight mark-up, and natural gas costs without mark-up.
See Note 5 — Segment Information of the Combined Notes to Consolidated Financial Statements for the presentation of DPL's revenue disaggregation.
The increase of $27 million and $61$32 million for the three and six months ended June 30, 2022,March 31, 2023, compared to the same period in 2021,2022, respectively, in Purchased power and fuel expense is fully offset in Operating revenues as part of regulatory required programs.
The changes in Operating and maintenance expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 |
| Increase (Decrease) | | Increase |
| BSC and PHISCO costs | $ | 4 | | | $ | 7 | |
| Credit loss expense | 2 | | | 4 | |
| Storm-related costs | — | | | 3 | |
| | | |
| Labor, other benefits, contracting and materials | 2 | | | 1 | |
| Other | (1) | | | — | |
| 7 | | | 15 | |
| Regulatory required programs | 1 | | | 2 | |
| Total increase | $ | 8 | | | $ | 17 | |
| | | | | | | |
| Three Months Ended
March 31, 2023 | | |
| (Decrease) Increase | | |
| Labor, other benefits, contracting and materials | $ | (3) | | | |
| Storm-related costs | (3) | | | |
| BSC and PHISCO costs | (1) | | | |
| Credit loss expense | (1) | | | |
| Pension and non-pension postretirement benefits expense | 1 | | | |
| | | |
| (7) | | | |
| Regulatory required programs | 1 | | | |
| Total decrease | $ | (6) | | | |
The changes in Depreciation and amortization expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended
June 30, 2022 |
| Increase | | Increase (Decrease) |
Depreciation and amortization(a) | $ | 5 | | | $ | 9 | |
| Regulatory asset amortization | — | | | (1) | |
| Regulatory required programs | — | | | 1 | |
| Total increase | $ | 5 | | | $ | 9 | |
| | | | | | | |
| Three Months Ended
March 31, 2023 | | |
| Increase (Decrease) | | |
Depreciation and amortization(a) | $ | 7 | | | |
| Regulatory asset amortization | (1) | | | |
| Regulatory required programs | (3) | | | |
| Total increase | $ | 3 | | | |
__________
(a)Depreciation and amortization increased primarily due toReflects ongoing capital expenditures.
Effective income tax rates were 8.7%16.7% and 3.2%6.7% for the three months ended June 30,March 31, 2023 and 2022, and 2021, respectively, and 7.2% and 6.5% for the six months ended June 30, 2022 and 2021, respectively. See Note 7 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the effective income tax rates.
Results of Operations — ACE
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended June 30, | | (Unfavorable)Favorable Variance | | Six Months Ended June 30, | | Favorable (Unfavorable) Variance |
| 2022 | | 2021 | | | 2022 | | 2021 | |
| Operating revenues | $ | 309 | | | $ | 319 | | | $ | (10) | | | $ | 658 | | | $ | 629 | | | $ | 29 | |
| | | | | | | | | | | |
| | | | | | | | | | | |
| Operating expenses | | | | | | | | | | | |
| Purchased power | 123 | | | 154 | | | 31 | | | 301 | | | 311 | | | 10 | |
| Operating and maintenance | 86 | | | 73 | | | (13) | | | 170 | | | 150 | | | (20) | |
| Depreciation and amortization | 72 | | | 40 | | | (32) | | | 118 | | | 87 | | | (31) | |
| Taxes other than income taxes | 2 | | | 2 | | | — | | | 4 | | | 4 | | | — | |
| Total operating expenses | 283 | | | 269 | | | (14) | | | 593 | | | 552 | | | (41) | |
| | | | | | | | | | | |
| Operating income | 26 | | | 50 | | | (24) | | | 65 | | | 77 | | | (12) | |
| Other income and (deductions) | | | | | | | | | | | |
| Interest expense, net | (17) | | | (14) | | | (3) | | | (32) | | | (29) | | | (3) | |
| Other, net | 2 | | | — | | | 2 | | | 5 | | | 2 | | | 3 | |
| Total other income and (deductions) | (15) | | | (14) | | | (1) | | | (27) | | | (27) | | | — | |
| Income before income taxes | 11 | | | 36 | | | (25) | | | 38 | | | 50 | | | (12) | |
| Income taxes | — | | | (1) | | | (1) | | | 1 | | | (1) | | | (2) | |
| Net income | $ | 11 | | | $ | 37 | | | $ | (26) | | | $ | 37 | | | $ | 51 | | | $ | (14) | |
| | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended March 31, | | Favorable (Unfavorable) Variance | | | | |
| 2023 | | 2022 | | | | | | |
| Operating revenues | $ | 353 | | | $ | 349 | | | $ | 4 | | | | | | | |
| | | | | | | | | | | |
| | | | | | | | | | | |
| Operating expenses | | | | | | | | | | | |
| Purchased power | 148 | | | 178 | | | 30 | | | | | | | |
| Operating and maintenance | 81 | | | 84 | | | 3 | | | | | | | |
| Depreciation and amortization | 67 | | | 47 | | | (20) | | | | | | | |
| Taxes other than income taxes | 2 | | | 2 | | | — | | | | | | | |
| Total operating expenses | 298 | | | 311 | | | 13 | | | | | | | |
| | | | | | | | | | | |
| Operating income | 55 | | | 38 | | | 17 | | | | | | | |
| Other income and (deductions) | | | | | | | | | | | |
| Interest expense, net | (16) | | | (14) | | | (2) | | | | | | | |
| Other, net | 5 | | | 3 | | | 2 | | | | | | | |
| Total other income and (deductions) | (11) | | | (11) | | | — | | | | | | | |
| Income before income taxes | 44 | | | 27 | | | 17 | | | | | | | |
| Income taxes | 11 | | | 1 | | | (10) | | | | | | | |
| Net income | $ | 33 | | | $ | 26 | | | $ | 7 | | | | | | | |
Three Months Ended June 30, 2022March 31, 2023 Compared to Three Months Ended June 30, 2021March 31, 2022. Net income decreasedincreased by $26$7 million primarily due to the absence of favorable weatherhigher transmission rates and volume as a result of the CIP, an increasedecreases in depreciation expense, various operating expenses, and timing of excess deferred tax amortization, partially offset by increases in distribution rates.
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net income decreased by $14 million primarily due to the absence of favorable weather and volume as a result of the CIP, an increase in depreciation expense, various operating expenses, and timing of excess deferred tax amortization, partially offset by increases in distribution rates.expenses.
The changes in Operating revenues consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended June 30, 2022 |
| (Decrease) Increase | | (Decrease) Increase |
| Weather | $ | (3) | | | $ | (3) | |
| Volume | (13) | | | (11) | |
| Distribution | 8 | | | 20 | |
| Transmission | (3) | | | 3 | |
| | | |
| (11) | | | 9 | |
| | | |
| | | |
| | | |
| | | |
| Regulatory required programs | 1 | | | 20 | |
| Total (decrease) increase | $ | (10) | | | $ | 29 | |
| | | | | | | |
| Three Months Ended
March 31, 2023 | | |
| Increase (Decrease) | | |
| | | |
| | | |
| Distribution | $ | 8 | | | |
| Transmission | 12 | | | |
| | | |
| 20 | | | |
| | | |
| | | |
| | | |
| | | |
| Regulatory required programs | (16) | | | |
| Total increase | $ | 4 | | | |
Revenue Decoupling. The demand for electricity is affected by weather and customer usage. However, Operating revenues from electric distribution in New Jersey are not impacted by abnormal weather or usage per customer as a result of the CIP which became effective, prospectively, in the third quarter of 2021. The CIP compares current distribution revenues by customer class to approved target revenues established in ACE’s most recent distribution base rate case. The CIP is calculated annually, and recovery is subject to certain conditions, including an earnings test and ceilings on customer rate increases. While Operating revenues are not impacted by abnormal weather or usage per customer, they are impacted by changes in the number of customers. See Note 3 — Regulatory Matters of the Combined Notes to the Consolidated Financial Statements for additional information.
Weather. Prior to the third quarter of 2021, the demand for electricity was affected by weather conditions. With respect to the electric business, very warm weather in summer months and very cold weather in winter months are referred to as “favorable weather conditions” because these weather conditions result in increased deliveries of electricity. Conversely, mild weather reduces demand. During the three and six months ended June 30, 2022 compared to the same period in 2021, Operating revenues related to weather decreased due to the absence of favorable impacts in the first and second quarter of 2022 as a result of the CIP.
Heating and cooling degree days are quantitative indices that reflect the demand for energy needed to heat or cool a home or business. Normal weather is determined based on historical average heating and cooling degree days for a 20-year period in ACE’s service territory. The changes in heating and cooling degree days in ACE’s service territory for the three and six months ended June 30, 2022 compared to same period in 2021 and normal weather consisted of the following:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Three Months Ended June 30, | | Normal | | % Change |
| Heating and Cooling Degree-Days | 2022 | | 2021 | | | 2022 vs. 2021 | | 2022 vs. Normal |
| Heating Degree-Days | 533 | | | 525 | | | 540 | | | 1.5 | % | | (1.3) | % |
| Cooling Degree-Days | 275 | | | 321 | | | 305 | | | (14.3) | % | | (9.8) | % |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Six Months Ended June 30, | | Normal | | % Change |
| Heating and Cooling Degree-Days | 2022 | | 2021 | | | 2022 vs. 2021 | | 2022 vs. Normal |
| Heating Degree-Days | 2,969 | | | 2,873 | | | 2,994 | | | 3.3 | % | | (0.8) | % |
| Cooling Degree-Days | 277 | | | 325 | | | 305 | | | (14.8) | % | | (9.2) | % |
Volume,exclusive of the effects of weather, decreased for the three and six months ended June 30, 2022 compared to the same period in 2021, due to the absence of favorable impacts in the first and second quarter of 2022 as a result of the CIP.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Electric Retail Deliveries to Customers (in GWhs) | Three Months Ended
June 30, | | % Change | | Weather - Normal % Change(b) | | Six Months Ended
June 30, | | % Change | | Weather - Normal % Change(b) |
| 2022 | | 2021 | | | | 2022 | | 2021 | | |
| Residential | 859 | | | 975 | | | (11.9) | % | | (9.7) | % | | 1,777 | | | 1,903 | | | (6.6) | % | | (6.0) | % |
| Small commercial & industrial | 362 | | | 333 | | | 8.7 | % | | 9.7 | % | | 701 | | | 638 | | | 9.9 | % | | 9.7 | % |
| Large commercial & industrial | 808 | | | 761 | | | 6.2 | % | | 6.7 | % | | 1,511 | | | 1,477 | | | 2.3 | % | | 2.3 | % |
| Public authorities & electric railroads | 11 | | | 11 | | | — | % | | (5.8) | % | | 25 | | | 24 | | | 4.2 | % | | 0.6 | % |
Total electric retail deliveries(a) | 2,040 | | | 2,080 | | | (1.9) | % | | (0.5) | % | | 4,014 | | | 4,042 | | | (0.7) | % | | (0.5) | % |
| | | | | | | | | | | |
| As of June 30, |
| Number of Electric Customers | 2022 | | 2021 |
| Residential | 501,494 | | | 499,436 | |
| Small commercial & industrial | 62,291 | | | 61,836 | |
| Large commercial & industrial | 3,085 | | | 3,243 | |
| Public authorities & electric railroads | 726 | | | 707 | |
| Total | 567,596 | | | 565,222 | |
__________
(a)Reflects delivery volumes from customers purchasing electricity directly from ACE and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges.
(b)Reflects the change in delivery volumes assuming normalized weather based on the historical 20-year average. | | | | | | | | | | | |
| As of March 31, |
| Number of Electric Customers | 2023 | | 2022 |
| Residential | 503,260 | | | 500,511 | |
| Small commercial & industrial | 62,230 | | | 62,124 | |
| Large commercial & industrial | 3,030 | | | 3,124 | |
| Public authorities & electric railroads | 726 | | | 724 | |
| Total | 569,246 | | | 566,483 | |
Distribution Revenue increased for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 20212022 due to higher distribution rates that became effective in January 2022.
Transmission Revenues. Under a FERC-approved formula, transmission revenue varies from year to year based upon fluctuations in the underlying costs and capital investments being recovered. Transmission revenue decreasedincreased for the three months ended June 30, 2022March 31, 2023 compared to the same period in 2021,2022, primarily due to decreases in underlying costs, partially offset by increases in capital investment. Transmission revenue increased for the six months ended June 30, 2022 compared to the same period in 2021, primarily due to an increase in capital investment.
Other Revenue includes rental revenue, service connection fees,investment and mutual assistance revenues.underlying costs.
Regulatory Required Programs represent revenues collected under approved riders to recover costs incurred for regulatory programs such as energy efficiency programs, Societal Benefits Charge, Transition Bonds,Bond Charge, and BGS procurement and administrative costs. The riders are designed to provide full and current cost recovery as well as a return in certain instances. The costs of these programs are included in Purchased power expense, Operating and maintenance expense, Depreciation and amortization expense, and Taxes other than income taxes. Customers have the choice to purchase electricity from competitive electric generation suppliers. Customer choice programs do not impact the volume of deliveries, as ACE remains the distribution service provider for all customers and charges a regulated rate for distribution service, which is recorded in Operating revenues. For customers that choose to purchase electric generation from competitive suppliers, ACE acts as the billing agent and therefore, ACE does not record Operating revenues or Purchased power expense related to the electricity. For customers that choose to purchase electric generation from ACE, ACE is permitted to recover the electricity, ZEC, and REC procurement costs without mark-up and therefore records equal and offsetting amounts in Operating revenues and Purchased power expense related to the electricity, ZECs, and RECs.
See Note 5 — Segment Information of the Combined Notes to Consolidated Financial Statements for the presentation of ACE's revenue disaggregation.
The decrease of $31 million and $10$30 million for the three and six months ended June 30, 2022March 31, 2023 compared to the same period in 2021, respectively,2022, in Purchased power expense is fully offset in Operating revenues as part of regulatory required programs.
The changes in Operating and maintenance expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended June 30, 2022 |
| Increase | | Increase |
| Labor, other benefits, contracting and materials | $ | 4 | | | $ | 4 | |
| BSC and PHISCO costs | 3 | | | 4 | |
| Storm-related costs | 1 | | | 2 | |
| Credit loss expense | 1 | | | — | |
| | | |
| Other | 1 | | | 3 | |
| 10 | | | 13 | |
| | | |
Regulatory required programs(a) | 3 | | | 7 | |
| Total increase | $ | 13 | | | $ | 20 | |
| | | | | | | |
| Three Months Ended
March 31, 2023 | | |
| (Decrease) Increase | | |
| Labor, other benefits, contracting and materials | $ | (2) | | | |
| | | |
| Storm-related costs | (2) | | | |
| | | |
| | | |
| Other | 2 | | | |
| (2) | | | |
| | | |
Regulatory required programs(a) | (1) | | | |
| Total decrease | $ | (3) | | | |
__________
(a)ACE is allowed to recover from or refund to customers the difference between its annual credit loss expense and the amounts collected in rates annually through the Societal Benefits Charge.
The changes in Depreciation and amortization expense consisted of the following:
| | | | | | | | | | | |
| Three Months Ended
June 30, 2022 | | Six Months Ended June 30, 2022 |
| Increase | | Increase |
Depreciation and amortization(a) | $ | 4 | | | $ | 7 | |
| Regulatory asset amortization | — | | | 1 | |
Regulatory required programs(b) | 28 | | | 23 | |
| Total increase | $ | 32 | | | $ | 31 | |
| | | | | | | |
| Three Months Ended
March 31, 2023 | | |
| Increase | | |
Depreciation and amortization(a) | $ | 7 | | | |
| Regulatory asset amortization | — | | | |
Regulatory required programs(b) | 13 | | | |
| Total increase | $ | 20 | | | |
__________
(a)Depreciation and amortization increased primarily due toReflects ongoing capital expenditures.expenditures and higher transmission depreciation rates effective September 2022.
(b)Regulatory required programs increased primarily due to the regulatory asset amortization of the PPA termination obligation which is fully offset in Operating revenues.
Effective income tax rates were 0.0%25.0% and (2.8)%3.7% for the three months ended June 30,March 31, 2023 and 2022, and 2021, respectively, and 2.6% and (2.0)% for the six months ended June 30, 2022 and 2021, respectively. The three and six months ended June 30, 2022 changes primarily reflect the timing of excess deferred tax amortization. See Note 7 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the effective income tax rates.
Liquidity and Capital Resources (All Registrants)
All results included throughout the liquidity and capital resources section are presented on a GAAP basis.
The Registrants’ operating and capital expenditures requirements are provided by internally generated cash flows from operations, as well as funds from external sources in the capital markets and through bank borrowings. The Registrants’ businesses are capital intensive and require considerable capital resources. Each of the Registrants annually evaluates its financing plan, dividend practices, and credit line sizing, focusing on maintaining its investment grade ratings while meeting its cash needs to fund capital requirements, including construction expenditures, retire debt, pay dividends, and fund pension and OPEB obligations. The Registrants spend a significant amount of cash on capital improvements and construction projects that have a long-term return on investment. Additionally, the Utility Registrants operate in rate-regulated environments in which the amount of new investment recovery may be delayed or limited and where such recovery takes place over an extended period of time. Each Registrant’s access to external financing on reasonable terms depends on its credit ratings and current overall capital market business conditions, including that of the utility industry in general. If these conditions deteriorate to the extent that the Registrants no longer have access to the capital markets at reasonable terms, the Registrants have access to credit facilities with aggregate bank commitments of $4.0 billion. The Registrants utilize their credit facilities to support their commercial paper programs, provide for other short-term borrowings, and to issue letters of credit. See the “Credit Matters and Cash Requirements” section below for additional information. The Registrants expect cash flows to be sufficient to meet operating expenses, financing costs, and capital expenditure requirements. See Note 10 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on the Registrants’ debt and credit agreements.
Cash flows related to ConstellationGeneration have not been presented as discontinued operations and are included in the Consolidated Statements of Cash Flows for all periods presented.only 2022. The Exelon Consolidated Statement of Cash Flows for the sixthree months ended June 30,March 31, 2022 includes one month of cash flows from Generation. The Exelon Consolidated Statement of Cash Flows for the six months ended June 30, 2021 includes six months of cash flows from Generation. This is the primary reason for the changes in cash flows as shown in the tables unless otherwise noted below.
Cash Flows from Operating Activities
The Utility Registrants' cash flows from operating activities primarily result from the transmission and distribution of electricity and, in the case of PECO, BGE, and DPL, gas distribution services. The Utility Registrants' distribution services are provided to an established and diverse base of retail customers. The Utility Registrants' future cash flows may be affected by the economy, weather conditions, future legislative initiatives, future regulatory proceedings with respect to their rates or operations, and their ability to achieve operating cost reductions. Additionally, ComEd is required to purchase CMCs from participating nuclear-powered generating facilities for a five-year period that began in June 2022, and all of its costs of doing so will be recovered through a rider. The price to be paid for each CMC is established through a competitive bidding process. ComEd will provide net payments to, or collect net payments from, customers for the difference between customer credits issued and the credit to be received from the participating nuclear-powered generating facilities. ComEd’s cash flows are affected by the establishment of CMC prices and the timing of recovering costs through the CMC regulatory asset.
See Note 3 — Regulatory Matters of the 2021 Recast2022 Form 10-K and Notes 3 — Regulatory Matters and 12 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for additional information on regulatory and legal proceedings and proposed legislation.
The following table provides a summary of the change in cash flows from operating activities for the sixthree months ended June 30,March 31, 2023 and 2022 and 2021 by Registrant:
| | Increase (decrease) in cash flows from operating activities | Increase (decrease) in cash flows from operating activities | Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE | Increase (decrease) in cash flows from operating activities | Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Net income (loss) | Net income (loss) | $ | 852 | | | $ | 25 | | | $ | 68 | | | $ | (20) | | | $ | (39) | | | $ | (18) | | | $ | (9) | | | $ | (14) | | Net income (loss) | $ | 71 | | | $ | 53 | | | $ | (40) | | | $ | 2 | | | $ | 25 | | | $ | 19 | | | $ | 4 | | | $ | 7 | |
| Adjustments to reconcile net income to cash: | Adjustments to reconcile net income to cash: | | Adjustments to reconcile net income to cash: | |
| Non-cash operating activities | Non-cash operating activities | (714) | | | (2) | | | 14 | | | 82 | | | 164 | | | 57 | | | 33 | | | 72 | | Non-cash operating activities | (683) | | | (126) | | | (7) | | | (61) | | | (8) | | | (17) | | | (9) | | | 14 | |
| Option premiums (paid), net | Option premiums (paid), net | (41) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Option premiums (paid), net | 39 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Collateral received, net | 732 | | | 58 | | | — | | | 188 | | | 403 | | | 85 | | | 180 | | | 137 | | |
| Collateral (paid) received, net | | Collateral (paid) received, net | (1,356) | | | (47) | | | — | | | (52) | | | (226) | | | (26) | | | (150) | | | (41) | |
| Income taxes | Income taxes | (167) | | | 15 | | | 25 | | | — | | | (1) | | | (4) | | | (8) | | | 6 | | Income taxes | (54) | | | 17 | | | 20 | | | 25 | | | 15 | | | 7 | | | 10 | | | 5 | |
| Pension and non-pension postretirement benefit contributions | Pension and non-pension postretirement benefit contributions | (26) | | | (5) | | | 2 | | | 12 | | | (30) | | | — | | | (1) | | | (4) | | Pension and non-pension postretirement benefit contributions | 530 | | | 153 | | | 12 | | | 48 | | | 60 | | | 1 | | | 1 | | | 6 | |
| Changes in regulatory assets and liabilities, net | (100) | | | (86) | | | (10) | | | 25 | | | (38) | | | 2 | | | 2 | | | (29) | | |
| Regulatory assets and liabilities, net | | Regulatory assets and liabilities, net | (293) | | | (330) | | | 19 | | | (23) | | | 45 | | | 4 | | | 27 | | | 6 | |
| Changes in working capital and other assets and liabilities | Changes in working capital and other assets and liabilities | 1,566 | | | 25 | | | (61) | | | 1 | | | (46) | | | (16) | | | (7) | | | (17) | | Changes in working capital and other assets and liabilities | 448 | | | 24 | | | 23 | | | 93 | | | 113 | | | 70 | | | 30 | | | 3 | |
| Increase in cash flows from operating activities | $ | 2,102 | | | $ | 30 | | | $ | 38 | | | $ | 288 | | | $ | 413 | | | $ | 106 | | | $ | 190 | | | $ | 151 | | |
| (Decrease) increase in cash flows from operating activities | | (Decrease) increase in cash flows from operating activities | $ | (1,298) | | | $ | (256) | | | $ | 27 | | | $ | 32 | | | $ | 24 | | | $ | 58 | | | $ | (87) | | | $ | — | |
Changes in the Registrants' cash flows from operations were generally consistent with changes in each Registrant’s respective results of operations, as adjusted by changes in working capital in the normal course of business, except as discussed below. See above for additional information related to cash flows from Generation. Significant operating cash flow impacts for the Registrants and Generation for the sixthree months ended June 30,March 31, 2023 and 2022 and 2021 were as follows:
•See Note 1415 — Supplemental Financial Information of the Combined Notes to Consolidated Financial Statements and the Registrants’ Consolidated Statements of Cash Flows for additional information on non-cash operating activities.
•Changes in collateral depended upon whether Generation was in a net mark-to-market liability or asset position, and collateral may have been required to be posted with or collected from its counterparties. In addition, the collateral posting and collection requirements differed depending on whether the transactions were on an exchange or in the over-the-counter markets. Changes in collateral for the Registrants are dependent upon the credit exposure of procurement contracts that may require suppliers to post collateral. The amount of cash collateral received from external counterparties increaseddecreased due to risingdecreasing energy prices. See Note 9 –— Derivative Financial Instruments for additional information.
•See Note 7 — Income Taxes of the Combined Notes to Consolidated Financial Statements and the Registrants' Consolidated Statements of Cash Flows for additional information on income taxes.
•Changes in Pension and non-pension postretirement benefit contributions relates to Exelon receiving an updated valuation of its pension and OPEB to reflect census data as of January 1, 2023. See Note 8 — Retirement Benefits of the Combined Notes to Consolidated Financial Statements for additional information.
•Changes in regulatory assets and liabilities, net, are due to the timing of cash payments for costs recoverable, or cash receipts for costs recovered, under our regulatory mechanisms differs from the recovery period of those costs. Included within the changes is energy efficiency spend for ComEd of $72 million and $50 million for the three months ended March 31, 2023 and 2022, respectively. Also included within the changes is energy efficiency and demand response programs spend for BGE, Pepco, DPL and ACE of $33 million, $14 million, $5 million, and $4 million for the three months ended March 31, 2023 and $26 million, $13 million, $6 million, and $2 million for the three months ended March 31, 2022, respectively. PECO had no energy efficiency and demand response programs spend recorded to the regulatory asset for the three months ended March 31,
2023 and 2022. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information on regulatory assets and liabilities.information.
•Changes in working capital and other assets and liabilities for the Utility Registrants and Exelon Corporate total $(74)totaled $125 million and for Generation total $1,640$323 million. The change for Generation primarily relates to the revolving accounts receivable financing arrangement. See Note 6 — Accounts Receivablearrangement which was entered into in April 2020. The change in working capital and other noncurrent assets and liabilities for Exelon Corporate and the Utility Registrants is dependent upon the normal course of operations for all Registrants. For ComEd, it is also dependent upon whether the participating nuclear-powered generating facilities are owed money from ComEd as a result of the 2021 Form 10-Kestablished pricing for CMCs. For the three months ended March 31, 2023, the established pricing resulted in a ComEd owing payments to nuclear-powered generating facilities, which is reported within the cash flows from operations as a change in accounts payable and the Collection of DPP discussion below for additional information.accrued expense.
Cash Flows from Investing Activities
The following table provides a summary of the change in cash flows from investing activities for the sixthree months ended June 30,March 31, 2023 and 2022 and 2021 by Registrant:
| | Increase (decrease) in cash flows from investing activities | Increase (decrease) in cash flows from investing activities | Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE | Increase (decrease) in cash flows from investing activities | Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Capital expenditures | Capital expenditures | $ | 533 | | | $ | (46) | | | $ | (81) | | | $ | 42 | | | $ | 113 | | | $ | 37 | | | $ | 17 | | | $ | 60 | | Capital expenditures | $ | 41 | | | $ | — | | | $ | 9 | | | $ | (47) | | | $ | (152) | | | $ | (46) | | | $ | (31) | | | $ | (74) | |
| | Investment in NDT fund sales, net | Investment in NDT fund sales, net | 72 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Investment in NDT fund sales, net | 28 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Collection of DPP | Collection of DPP | (2,040) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Collection of DPP | (169) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Proceeds from sales of assets and businesses | Proceeds from sales of assets and businesses | (708) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Proceeds from sales of assets and businesses | (16) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Changes in intercompany money pool | — | | | — | | | — | | | — | | | — | | | — | | | (64) | | | — | | |
| | | Other investing activities | Other investing activities | (13) | | | 3 | | | 1 | | | (3) | | | 5 | | | 4 | | | 1 | | | — | | Other investing activities | 64 | | | (6) | | | (2) | | | — | | | 6 | | | 7 | | | (1) | | | — | |
| (Decrease) increase in cash flows from investing activities | (Decrease) increase in cash flows from investing activities | $ | (2,156) | | | $ | (43) | | | $ | (80) | | | $ | 39 | | | $ | 118 | | | $ | 41 | | | $ | (46) | | | $ | 60 | | (Decrease) increase in cash flows from investing activities | $ | (52) | | | $ | (6) | | | $ | 7 | | | $ | (47) | | | $ | (146) | | | $ | (39) | | | $ | (32) | | | $ | (74) | |
Significant investing cash flow impacts for the Registrants for sixthree months ended June 30,March 31, 2023 and 2022 and 2021 were as follows:
•VariancesChanges in capital expenditures are primarily due to the timing of cash expenditures for capital projects. See the "Credit Matters and Cash Requirements" section below for additional information on projected capital expenditure spending.spending for the Utility Registrants. See Note 2 — Discontinued Operations of the Combined Notes to Consolidated Financial Statements for capital expenditures related to Generation prior to the separation.
•Collection of DPPrelates to theGeneration's revolving accounts receivable financing agreement which Generation entered into in April of 2020. See Note 6 — Accounts Receivable of the 2021 Form 10-K for additional information on the transaction and the DPP, including the $400 million of additional funding received in February and March of 2021.
•Proceeds from sales of assets and businesses decreased primarily due to the sale of a significant portion of Generation's solar business in 2021. See Note 2 — Mergers, Acquisitions, and Dispositions of the 2021 Form 10-K for additional information.
•Changes in intercompany money pool are driven by short-term borrowing needs. Refer below for more information regarding the intercompany money pool.
Cash Flows from Financing Activities
The following table provides a summary of the change in cash flows from financing activities for the sixthree months ended June 30,March 31, 2023 and 2022 and 2021 by Registrant:
| | Increase (decrease) in cash flows from financing activities | Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE | |
| (Decrease) increase in cash flows from financing activities | | (Decrease) increase in cash flows from financing activities | Exelon | | ComEd | | PECO | | BGE | | PHI | | Pepco | | DPL | | ACE |
| Changes in short-term borrowings, net | Changes in short-term borrowings, net | $ | 369 | | | $ | 290 | | | $ | 210 | | | $ | (130) | | | $ | (389) | | | $ | (251) | | | $ | (3) | | | $ | (135) | | Changes in short-term borrowings, net | $ | (1,380) | | | $ | (168) | | | $ | (94) | | | $ | (285) | | | $ | 54 | | | $ | (124) | | | $ | 34 | | | $ | 144 | |
| Long-term debt, net | Long-term debt, net | 1,619 | | | 50 | | | (375) | | | (100) | | | 124 | | | 50 | | | — | | | 74 | | Long-term debt, net | (1,227) | | | 225 | | | — | | | — | | | (250) | | | (150) | | | — | | | (100) | |
| Changes in intercompany money pool | Changes in intercompany money pool | — | | | — | | | 40 | | | — | | | 29 | | | 64 | | | — | | | — | | Changes in intercompany money pool | — | | | — | | | (65) | | | — | | | (31) | | | — | | | — | | | — | |
| | Dividends paid on common stock | Dividends paid on common stock | 84 | | | (36) | | | (31) | | | (4) | | | — | | | (177) | | | 7 | | | 191 | | Dividends paid on common stock | (26) | | | (43) | | | (1) | | | (4) | | | — | | | (6) | | | (1) | | | (2) | |
| | Distributions to member | Distributions to member | — | | | — | | | — | | | — | | | 19 | | | — | | | — | | | — | | Distributions to member | — | | | — | | | — | | | — | | | (10) | | | — | | | — | | | — | |
| Contributions from(to) parent/member | — | | | (60) | | | (168) | | | 186 | | | 144 | | | 249 | | | 24 | | | (130) | | |
| Contributions from parent/member | | Contributions from parent/member | — | | | 19 | | | 103 | | | 237 | | | (299) | | | (144) | | | (45) | | | (110) | |
| Transfer of cash, restricted cash, and cash equivalents to Constellation | Transfer of cash, restricted cash, and cash equivalents to Constellation | (2,594) | | | — | | | — | | | — | | | — | | | — | | | — | | | — | | Transfer of cash, restricted cash, and cash equivalents to Constellation | 2,594 | | | — | | | — | | | — | | | — | | | — | | | — | | | — | |
| Other financing activities | Other financing activities | (50) | | | (1) | | | (4) | | | (1) | | | (4) | | | (4) | | | (1) | | | — | | Other financing activities | 3 | | | (1) | | | 1 | | | 1 | | | (8) | | | (9) | | | — | | | 2 | |
| (Decrease) increase in cash flows from financing activities | (Decrease) increase in cash flows from financing activities | $ | (572) | | | $ | 243 | | | $ | (328) | | | $ | (49) | | | $ | (77) | | | $ | (69) | | | $ | 27 | | | $ | — | | (Decrease) increase in cash flows from financing activities | $ | (36) | | | $ | 32 | | | $ | (56) | | | $ | (51) | | | $ | (544) | | | $ | (433) | | | $ | (12) | | | $ | (66) | |
Significant financing cash flow impacts for the Registrants for the sixthree months ended June 30,March 31, 2023 and 2022 and 2021 were as follows:
•Changes in short-term borrowings, net, is driven by repayments on and issuances of notes due in less than 365 days. Refer toSee Note 10 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on short-term borrowings for the Registrants. These changes also included repayments of $552 million in commercial paper and term loans by Generation prior to the separation.
•Long-term debt, net, varies due to debt issuances and redemptions each year. Refer toSee Note 10 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on debt issuances. Refer to the debt redemptions table below for additional information.
•Changes in intercompany money pool are driven by short-term borrowing needs. Refer below for more information regarding the intercompany money pool.
•Exelon’s ability to pay dividends on its common stock depends on the receipt of dividends paid by its operating subsidiaries. The payments of dividends to Exelon by its subsidiaries in turn depend on their results of operations and cash flows and other items affecting retained earnings. See Note 1718 — Commitments and Contingencies of the 2021 Recast2022 Form 10-K for additional information on dividend restrictions. See below for quarterly dividends declared.
•Refer to Note 2 -— Discontinued Operations for the transfer of cash, restricted cash, and cash equivalents to Constellation related to the separation.
•For the six months ended June 30, 2022, other financing activities primarily consists of debt issuance costs. See Note 10 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information of the Registrants’ debt issuances.
Debt
See Note 10 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on the Registrants’ debt issuances.
During the sixthree months ended June 30, 2022,March 31, 2023, the following long-term debt was retired and/or redeemed:
| | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Company | | Type | | Interest Rate | | | Maturity | | Amount |
| Exelon | | SMBC Term Loan Agreement | | SOFR plus 0.65% | | | July 21, 2023 | | $ | 300 | |
| Exelon | | US Bank Term Loan Agreement | | SOFR plus 0.65% | | | July 21, 2023 | | 300 | |
| | | | | | | | | |
| Exelon | | PNC Term Loan Agreement | | SOFR plus 0.65% | | | July 24, 2023 | | 250 | |
| Exelon | | Long-Term Software License Agreement | | 3.70 | % | | | August 9, 2025 | | 6 | |
| Exelon | | Long-Term Software License Agreement | | 3.70 | % | | | August 9, 2025 | | 1 | |
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Company(a) | | Type | | Interest Rate | | | Maturity | | Amount |
| Exelon | | Junior Subordinated Notes | | 3.50 | % | | | May 2, 2022 | | $ | 1,150 | |
| Exelon | | Long-Term Software License Agreement | | 3.96 | % | | | May 1, 2024 | | 2 | |
| PECO | | First Mortgage Bonds | | 2.375 | % | | | September 15, 2022 | | 350 | |
| Pepco | | First Mortgage Bonds | | 3.05 | % | | | April 1, 2022 | | 200 | |
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__________
(a)On July 5, 2022, BGE redeemed $250 million of 2.80% senior notes originally due on August 15, 2022.
Dividends
Quarterly dividends declared by the Exelon Board of Directors during the sixthree months ended June 30, 2022March 31, 2023 and for the thirdsecond quarter of 20222023 were as follows:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Period | | Declaration Date | | Shareholder of Record Date | | Dividend Payable Date | | Cash per Share(a) |
First Quarter 20222023 | | February 8, 202214, 2023 | | February 25, 202227, 2023 | | March 10, 20222023 | | $ | 0.33750.3600 | |
Second Quarter 20222023 | | April 26, 202225, 2023 | | May 13, 202215, 2023 | | June 10, 20229, 2023 | | $ | 0.33750.3600 | |
Third Quarter 2022 | | July 26, 2022 | | August 15, 2022 | | September 9, 2022 | | $ | 0.3375 | |
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| | | | | | | | |
__________
(a)Exelon's Board of Directors approved an updated dividend policy for 2022.2023. The 20222023 quarterly dividend will be $0.3375$0.36 per share.
Credit Matters and Cash Requirements
The Registrants fund liquidity needs for capital investment, working capital, energy hedging, and other financial commitments through cash flows from continuing operations, public debt offerings, commercial paper markets, and large, diversified credit facilities. The credit facilities include $4.0 billion in aggregate total commitments of which $3.6$3.2 billion was available to support additional commercial paper as of June 30, 2022,March 31, 2023, and of which no financial institution has more than 6% of the aggregate commitments for the Registrants. The Registrants had access to the commercial paper markets and had availability under their revolving credit facilities during the sixthree months ended June 30, 2022March 31, 2023 to fund their short-term liquidity needs, when necessary. On February 1, 2022, Exelon Corporate and the Utility Registrants each entered intohave a new 5-year revolving credit facility that replaced its existing syndicated revolving credit facility. See Note 10 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information. The Registrants routinely review the sufficiency of their liquidity position, including appropriate sizing of credit facility commitments, by performing various stress test scenarios, such as commodity price movements, increases in margin-related transactions, changes in hedging levels, and the impacts of hypothetical credit downgrades. The Registrants have continued to closely monitor events in the financial markets and the financial institutions associated with the credit facilities, including monitoring credit ratings and outlooks, credit default swap levels, capital raising, and merger activity. See PART I. ITEM 1A. RISK FACTORS of the 20212022 Form 10-K for additional information regarding the effects of uncertainty in the capital and credit markets.
The Registrants believe their cash flows from operating activities, access to credit markets, and their credit facilities provide sufficient liquidity to support the estimated future cash requirements.
On August 4, 2022, Exelon anticipates issuingexecuted an equity distribution agreement (“Equity Distribution Agreement”) with certain sales agents and forward sellers and certain forward purchasers establishing an ATM equity distribution program under which it may offer and sell shares of its common stock, having an aggregate gross sales price of up to $1.0 billion of registeredbillion. Exelon has no obligation to offer or sell any shares of common stock through 2025.under the Equity Distribution Agreement and may at any time suspend or terminate offers and sales under the Equity Distribution Agreement. As of March 31, 2023, Exelon plans to establish a $1.0 billion at-the-market (ATM) program, under which Exelon can issue registeredhas not issued any shares of common stock through designated broker-dealers at prevailing market prices. Exelon anticipates issuing $500 million in 2022 throughunder the ATM a one-time common equity offering, or a combination of these methods.
Pursuant to the Separation Agreement between Exelonprogram and Constellation, Exelon made a cash payment of $1.75 billion to Generation on January 31, 2022. See Note 2 — Discontinued Operations of the Combined Notes to Consolidated Financial Statements for additional information on the separation.has not entered into any forward sale agreements.
The following table presents the incremental collateral that each Utility Registrant would have been required to provide in the event each Utility Registrant lost its investment grade credit rating at June 30, 2022March 31, 2023 and available credit facility capacity prior to any incremental collateral at June 30, 2022:March 31, 2023:
| | | PJM Credit Policy Collateral | | Other Incremental Collateral Required(a) | | Available Credit Facility Capacity Prior to Any Incremental Collateral | | PJM Credit Policy Collateral | | Other Incremental Collateral Required(a) | | Available Credit Facility Capacity Prior to Any Incremental Collateral |
| ComEd | ComEd | $ | 12 | | | $ | — | | | $ | 995 | | ComEd | $ | 17 | | | $ | — | | | $ | 586 | |
| PECO | PECO | 2 | | | 37 | | | 390 | | PECO | 1 | | | 39 | | | 455 | |
| BGE | BGE | 3 | | | 75 | | | 600 | | BGE | 3 | | | 73 | | | 357 | |
| | Pepco | Pepco | 3 | | | — | | | 257 | | Pepco | 4 | | | — | | | 300 | |
| DPL | DPL | 2 | | | 15 | | | 300 | | DPL | 4 | | | 14 | | | 300 | |
| ACE | ACE | 1 | | | — | | | 300 | | ACE | 2 | | | — | | | 300 | |
__________
(a)Represents incremental collateral related to natural gas procurement contracts.
Capital Expenditure Spending
As of June 30, 2022,March 31, 2023, the most recent estimates of capital expenditures for plant additions and improvements for 20222023 are as follows:
| | (In millions) | (In millions) | Transmission | | Distribution | | Gas | | Total | (In millions) | Transmission | | Distribution | | Gas | | Total(a) |
| Exelon | Exelon | N/A | | N/A | | N/A | | $ | 6,900 | | Exelon | N/A | | N/A | | N/A | | $ | 7,175 | |
| ComEd | ComEd | 475 | | | 2,000 | | | N/A | | 2,475 | | ComEd | 500 | | | 2,075 | | | N/A | | 2,550 | |
| PECO | PECO | 200 | | | 825 | | | 325 | | | 1,350 | | PECO | 75 | | | 975 | | | 325 | | | 1,375 | |
| BGE | BGE | 250 | | | 500 | | | 475 | | | 1,225 | | BGE | 325 | | | 525 | | | 475 | | | 1,325 | |
| PHI | PHI | 625 | | | 1,150 | | | 75 | | | 1,850 | | PHI | 550 | | | 1,225 | | | 125 | | | 1,900 | |
| Pepco | Pepco | 275 | | | 625 | | | N/A | | 900 | | Pepco | 250 | | | 650 | | | N/A | | 900 | |
| DPL | DPL | 150 | | | 250 | | | 75 | | | 475 | | DPL | 175 | | | 275 | | | 125 | | | 575 | |
| ACE | ACE | 200 | | | 275 | | | N/A | | 475 | | ACE | 125 | | | 300 | | | N/A | | 425 | |
__________
(a)Numbers rounded to the nearest $25M and may not sum due to rounding.
Projected capital expenditures and other investments are subject to periodic review and revision to reflect changes in economic conditions and other factors.
Pension and Other PostretirementRetirement Benefits
Management considers various factors when making pension funding decisions, including actuarially determined minimum contribution requirements under ERISA, contributions required to avoid benefit restrictions and at-risk status as defined by the Pension Protection Act of 2006 (the Act), management of the pension obligation, and regulatory implications. The Act requires the attainment of certain funding levels to avoid benefit restrictions (such as an inability to pay lump sums or to accrue benefits prospectively), and at-risk status (which triggers higher minimum contribution requirements and participant notification). The projected contributions reflect a funding strategy to make levelized annual contributions with the objective of achieving 100% funded status on an ABO basis over time. This level funding strategy helps minimize volatility of future period required pension contributions. Post-separation, Exelon'sExelon’s estimated annual qualified pension contributions will be approximately $313$20 million in 2022. In connection with the separation, additional qualified pension contributions of $207 million and $33 million were completed on February 1, 2022 and March 2, 2022, respectively.2023. Unlike the qualified pension plans, Exelon’s non-qualified pension plans are not funded, given that they are not subject to statutory minimum contribution requirements.
While OPEB plans are also not subject to statutory minimum contribution requirements, Exelon does fund certain of its plans. For Exelon's funded OPEB plans, contributions generally equal accounting costs, however, Exelon’s management has historically considered several factors in determining the level of contributions to its OPEB plans, including liabilities management, levels of benefit claims paid, and regulatory implications (amounts deemed prudent to meet regulatory expectations and best assure continued rate recovery).
To the extent interest rates decline significantly or the pension and OPEB plans earn less than the expected asset returns, annual pension contribution requirements in future years could increase. Conversely, to the extent interest rates increase significantly or the pension and OPEB plans earn greater than the expected asset returns, annual pension and OPEB contribution requirements in future years could decrease. Additionally, expected contributions could change if Exelon changes its pension or OPEB funding strategy.
See Note 14 — Retirement Benefits of the Combined Notes to Consolidated Financial Statements of the 2022 Form 10-K for additional information on pension and OPEB contributions.
Credit Facilities
Exelon Corporate, ComEd, and BGE meet their short-term liquidity requirements primarily through the issuance of commercial paper. PECO meets its short-term liquidity requirements primarily through the issuance of
commercial paper and borrowings from the Exelon intercompany money pool. Pepco, DPL, and ACE meet their short-term liquidity requirements primarily through the issuance of commercial paper and borrowings from the PHI intercompany money pool. PHI Corporate meets its short-term liquidity requirements primarily through the issuance of short-term notes and the Exelon intercompany money pool. The Registrants may use their respective
credit facilities for general corporate purposes, including meeting short-term funding requirements and the issuance of letters of credit.
See Note 10 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on the Registrants’ credit facilities and short term borrowing activity.
Security Ratings
The Registrants’ access to the capital markets, including the commercial paper market, and their respective financing costs in those markets, may depend on the securities ratings of the entity that is accessing the capital markets.
The Registrants’ borrowings are not subject to default or prepayment as a result of a downgrading of securities, although such a downgrading of a Registrant’s securities could increase fees and interest charges under that Registrant’s credit agreements.
As part of the normal course of business, the Registrants enter into contracts that contain express provisions or otherwise permit the Registrants and their counterparties to demand adequate assurance of future performance when there are reasonable grounds for doing so. In accordance with the contracts and applicable contracts law, if the Registrants are downgraded by a credit rating agency, it is possible that a counterparty would attempt to rely on such a downgrade as a basis for making a demand for adequate assurance of future performance, which could include the posting of collateral. See Note 9 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information on collateral provisions.
The credit ratings for ComEd, PECO, BGE,Exelon and DPLthe Utility Registrants did not change for the sixthree months ended June 30, 2022. On January 14, 2022, Fitch lowered Exelon Corporate's long-term and senior unsecured ratings from BBB+ to BBB and affirmed the short-term rating of F2. In addition, Fitch upgraded Pepco, ACE, and PHI's long-term rating from BBB to BBB+ and upgraded Pepco and ACE's senior secured rating from A- to A.March 31, 2023.
Intercompany Money Pool
To provide an additional short-term borrowing option that will generally be more favorable to the borrowing participants than the cost of external financing, both Exelon and PHI operate an intercompany money pool. Maximum amounts contributed to and borrowed from the money pool by participant and the net contribution or borrowing as of June 30, 2022,March 31, 2023, are presented in the following table. Pepco, DPL, and ACE had no activity within the PHI intercompany money pool during the sixthree months ended June 30, 2022.March 31, 2023.
| | | | | | | | | | | | | | | | | | | | |
| | During the Six Months Ended June 30, 2022 | | As of June 30, 2022 |
| Exelon Intercompany Money Pool | | Maximum
Contributed | | Maximum
Borrowed | | Contributed
(Borrowed) |
| Exelon Corporate | | $ | 396 | | | $ | — | | | $ | 287 | |
| PECO | | 60 | | | (105) | | | — | |
| BSC | | — | | | (377) | | | (308) | |
| PHI Corporate | | — | | | (54) | | | (24) | |
| PCI | | 50 | | | — | | | 45 | |
| | | | | | | | | | | | | | | | | | | | |
| | During the Six Months Ended June 30, 2022 | | As of June 30, 2022 |
| PHI Intercompany Money Pool | | Maximum
Contributed | | Maximum
Borrowed | | Contributed
(Borrowed) |
| Pepco | | $ | — | | | $ | (85) | | | $ | (73) | |
| DPL | | 85 | | | — | | | 73 | |
| | | | | | | | | | | | | | | | | | | | |
| | During the Three Months Ended March 31, 2023 | | As of March 31, 2023 |
| Exelon Intercompany Money Pool | | Maximum
Contributed | | Maximum
Borrowed | | Contributed
(Borrowed) |
| Exelon Corporate | | $ | 510 | | | $ | — | | | $ | 266 | |
| PECO | | — | | | (238) | | | — | |
| BSC | | — | | | (327) | | | (259) | |
| PHI Corporate | | — | | | (52) | | | (52) | |
| PCI | | 45 | | | — | | | 45 | |
Shelf Registration Statements
Exelon and the Utility Registrants have a currently effective combined shelf registration statement, unlimited in amount, filed with the SEC, that will expire in August 2022.2025. The ability of each Registrant to sell securities off the shelf registration statement or to access the private placement markets will depend on a number of factors at the time of the proposed sale, including other required regulatory approvals, as applicable, the current financial condition of the Registrant, its securities ratings and market conditions.
Regulatory Authorizations
The Utility Registrants are required to obtain short-term and long-term financing authority from Federal and State Commissions as follows:
| | | As of June 30, 2022 | | As of March 31, 2023 |
| | Short-term Financing Authority | | Remaining Long-term Financing Authority | | Short-term Financing Authority | | Remaining Long-term Financing Authority |
| Commission | | Expiration Date | | Amount | Commission | | Expiration Date | | Amount | Commission | | Expiration Date | | Amount | Commission | | Expiration Date | | Amount |
ComEd(a) | ComEd(a) | | FERC | | December 31, 2023 | | $ | 2,500 | | | ICC | | January 1, 2025 | | $ | 1,343 | | ComEd(a) | | FERC | | December 31, 2023 | | $ | 2,500 | | | ICC | | January 1, 2025 | | $ | 368 | |
PECO(b) | PECO(b) | | FERC | | December 31, 2023 | | 1,500 | | | PAPUC | | December 31, 2024 | | 1,550 | | PECO(b) | | FERC | | December 31, 2023 | | 1,500 | | | PAPUC | | December 31, 2024 | | 1,125 | |
BGE | BGE | | FERC | | December 31, 2023 | | 700 | | | MDPSC | | N/A | | — | | BGE | | FERC | | December 31, 2023 | | 700 | | | MDPSC | | N/A | | 1,800 | |
Pepco(c)(b) | Pepco(c)(b) | | FERC | | December 31, 2023 | | 500 | | | MDPSC / DCPSC | | 2022 & 2025 | | 1,625 | | Pepco(c)(b) | | FERC | | December 31, 2023 | | 500 | | | MDPSC / DCPSC | | December 31, 2025 | | 1,150 | |
DPL | DPL | | FERC | | December 31, 2023 | | 500 | | | MDPSC / DEPSC | | December 31, 2022 | | 47 | | DPL | | FERC | | December 31, 2023 | | 500 | | | MDPSC / DEPSC | | December 31, 2025 | | 1,075 | |
ACE(d) | ACE(d) | | NJBPU | | December 31, 2023 | | 350 | | | NJBPU | | December 31, 2022 | | — | | ACE(d) | | NJBPU | | December 31, 2023 | | 350 | | | NJBPU | | December 31, 2024 | | 625 | |
__________
(a)On November 18, 2021, ComEdDecember 21, 2022, BGE received approval from the ICCMDPSC for $2$1.8 billion in new money long-term debt financing authority with an effective date of January 1, 2022.4, 2023.
(b)On December 2, 2021, PECO received approval from the PAPUC for $2.5 billion in new long-term debtThe financing authority filed with an effective date of January 1, 2022.
(c)As of June 30, 2022, Pepco had $225 million in long-term financing authority from the MDPSC and DCPSC, which hasdoes not have an expiration date, of December 31, 2022. On June 9, 2022 and June 30, 2022, Pepco received approval fromwhile the MDPSC and DCPSC, respectively, for $1.4 billion in new long-term financing authority. The long-term financing authority became effective on the date of respective approvals andfiled with DEPSC has an expiration date of December 31, 2025.
(d)On July 13, 2022, ACE received approval from the NJBPU for $700 million in new long-term debt financing authority with an effective date of July 20, 2022.
ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK
The Registrants hold commodity and financial instruments that are exposed to the following market risks:
•Commodity price risk, which is discussed further below.
•Counterparty credit risk associated with non-performance by counterparties on executed derivative instruments and participation in all, or some of the established, wholesale spot energy markets that are administered by PJM. The credit policies of PJM may, under certain circumstances, require that losses arising from the default of one member on spot energy market transactions be shared by the remaining participants. See Note 9 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for a detailed discussion of counterparty credit risk related to derivative instruments.
•Equity price and interest rate risk associated with Exelon’s pension and OPEB plan trusts. See Note 138 — Retirement Benefits of the 2021 Recast2022 Form 10-K for additional information.
•Interest rate risk associated with changes in interest rates for the Registrants’ outstanding long-term debt. This risk is significantly reduced as substantially all of the Registrants’ outstanding debt has fixed interest rates. There is inherent interest rate risk related to refinancing maturing debt by issuing new long-term debt. The Registrants use a combination of fixed-rate and variable-rate debt to manage interest rate exposure. See Note 10 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information. In addition, Exelon may utilize interest rate derivatives to lock in rate levels in anticipation of future financings, which are typically designated as cash flow hedges, or to lock in rate levels on borrowings, which are typically designated as economic hedges. See Note 9 – Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information.
•Electric operating revenues risk associated with ComEd's distribution formula rate. ComEd's ROE for its electric distribution service through 2023 is directly correlated to yields on U.S. Treasury bonds. Exelon Corporate may utilize interest rate derivatives to mitigate volatility and manage risk to Exelon, which are typically accounted for as economic hedges. See Note 9 – Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information.
The Registrants operate primarily under cost-based rate regulation limiting exposure to the effects of market risk. Hedging programs are utilized to reduce exposure to energy and natural gas price volatility and have no direct earnings impacts as the costs are fully recovered through regulatory-approved recovery mechanisms.
Exelon manages these risks through risk management policies and objectives for risk assessment, control and valuation, counterparty credit approval, and the monitoring and reporting of risk exposures. Risk management issues are reported to Exelon’s Executive Committee, the Risk Management Committees of each Utility Registrant, and the Audit and Risk Committee of Exelon’s Board of Directors.
Commodity Price Risk
Commodity price risk is associated with price movements resulting from changes in supply and demand, fuel costs, market liquidity, weather conditions, governmental regulatory and environmental policies, and other factors. To the extent the total amount of energy Exelon purchases differs from the amount of energy it has contracted to sell, Exelon is exposed to market fluctuations in commodity prices. Exelon seeks to mitigate its commodity price risk through the sale and purchase of electricity and natural gas.
ComEd entered into 20-year floating-to-fixed renewable energy swap contracts beginning in June 2012, which are considered an economic hedge and have changes in fair value recorded to an offsetting regulatory asset or liability. ComEd has block energy contracts to procure electric supply that are executed through a competitive procurement process, which are considered derivatives and qualify for NPNS, and as a result are accounted for on an accrual basis of accounting. PECO, BGE, Pepco, DPL, and ACE have contracts to procure electric supply that are executed through a competitive procurement process. PECO, BGE, Pepco, DPL, and ACE have certain full requirements contracts, which are considered derivatives and qualify for NPNS, and as a result are accounted for on an accrual basis of accounting. Other full requirements contracts are not derivatives.
PECO, BGE, and DPL also have executed derivative natural gas contracts, which either qualify for NPNS, or have no mark-to-market balances because the derivatives are index priced, to hedge their long-term price risk in the natural gas market. The hedging programs for natural gas procurement have no direct impact on their financial statements.
For additional information on these contracts, see Note 9 — Derivative Financial Instruments and Note 11 — Fair Value of Financial Assets and Liabilities of the Combined Notes to Consolidated Financial Statements.
The following table presents the maturity and source of fair value for Exelon’s and ComEd’s mark-to-market commodity contract net liabilities. These net liabilities are associated with ComEd’s floating-to-fixed energy swap
contracts with unaffiliated suppliers. The table provides two fundamental pieces of information. First, the table provides the source of fair value used in determining the carrying amount of Exelon's and ComEd's total mark-to-market net liabilities. Second, the table shows the maturity, by year, of Exelon's and ComEd's commodity contract net liabilities giving an indication of when these mark-to-market amounts will settle and either generate or require cash. See Note 11 — Fair Value of Financial Assets and Liabilities of the Combined Notes to Consolidated Financial Statements for additional information regarding fair value measurements and the fair value hierarchy.
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Maturities Within | | Total Fair
Value |
| 2022 | | 2023 | | 2024 | | 2025 | | 2026 | | 2027 and Beyond | |
| Prices based on model or other valuation methods (Level 3) | $ | 11 | | | $ | (2) | | | $ | (14) | | | $ | (16) | | | $ | (15) | | | $ | (52) | | | $ | (88) | |
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| Maturities Within | | Total Fair
Value |
Commodity derivative contracts(a): | 2023 | | 2024 | | 2025 | | 2026 | | 2027 | | 2028 and Beyond | |
| Prices based on model or other valuation methods (Level 3) | $ | (20) | | | $ | (16) | | | $ | (14) | | | $ | (12) | | | $ | (10) | | | $ | (26) | | | $ | (98) | |
_________
(a)Represents ComEd's net liabilities associated with the floating-to-fixed energy swap contracts with unaffiliated suppliers.
ITEM 4. CONTROLS AND PROCEDURES
During the secondfirst quarter of 2022,2023, each of the Registrants' management, including its principal executive officer and principal financial officer, evaluated its disclosure controls and procedures related to the recording, processing, summarizing, and reporting of information in its periodic reports that it files with the SEC. These disclosure controls and procedures have been designed by the Registrants to ensure that (a) material information relating to that Registrant, including its consolidated subsidiaries, is accumulated and made known to that Registrant's management, including its principal executive officer and principal financial officer, by other employees of that Registrant and its subsidiaries as appropriate to allow timely decisions regarding required disclosure, and (b) this information is recorded, processed, summarized, evaluated, and reported, as applicable, within the time periods specified in the SEC’s rules and forms. Due to the inherent limitations of control systems, not all misstatements may be detected. These inherent limitations include the realities that judgments in decision-making can be faulty and that breakdowns can occur because of simple error or mistake. Additionally, controls could be circumvented by the individual acts of some persons or by collusion of two or more people.
Accordingly, as of June 30, 2022,March 31, 2023, the principal executive officer and principal financial officer of each of the Registrants concluded that such Registrant’s disclosure controls and procedures were effective to accomplish its objectives. The Registrants continually strive to improve their disclosure controls and procedures to enhance the quality of its financial reporting and to maintain dynamic systems that change as conditions warrant. There were no changes in internal control over financial reporting during the secondfirst quarter of 20222023 that materially affected, or are reasonably likely to materially affect, any of the Registrants' internal control over financial reporting.
PART II — OTHER INFORMATION
ITEM 1. LEGAL PROCEEDINGS
The Registrants are parties to various lawsuits and regulatory proceedings in the ordinary course of their respective businesses. For information regarding material lawsuits and proceedings, see (a) ITEM 3. LEGAL PROCEEDINGS of the 20212022 Form 10-K, (b) Notes 3 — Regulatory Matters and 1718 — Commitments and Contingencies of the 2021 Recast2022 Form 10-K, and (c) Notes 3 — Regulatory Matters and 12 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements in PART I, ITEM 1. FINANCIAL STATEMENTS of this Report. Such descriptions are incorporated herein by these references.
ITEM 1A. RISK FACTORS
Risks Related to All Registrants
At June 30, 2022,March 31, 2023, the Registrants' risk factors were consistent with the risk factors described in the 20212022 Form 10-K in ITEM 1A. RISK FACTORS, except for the updates below.
The Registrants are subject to physical security and cybersecurity risks (All Registrants).
The Registrants face physical security and cybersecurity risks. Threat sources, including sophisticated nation-state actors, continue to seek to exploit potential vulnerabilities in the electric and natural gas utility industry, grid infrastructure, and other energy infrastructures, and these attacks and disruptions, both physical and cyber, are becoming increasingly sophisticated and dynamic. Continued implementation of advanced digital technologies
increases the potentially unfavorable impacts of such attacks. Additionally, the U.S. government has warned that the Ukraine conflict may increase the risks of attacks targeting critical infrastructure in the United States.
A security breach of the Registrants' physical assets or information systems or those of the Registrants competitors, vendors, business partners and interconnected entities in RTOs and ISOs, or regulators could impact the operation of the generation fleet and/or reliability of the transmission and distribution system or result in the theft or inappropriate release of certain types of information, including critical infrastructure information, sensitive customer, vendor, and employee data, trading or other confidential data. The risk of these system-related events and security breaches occurring continues to intensify, and while the Registrants have been, and will likely continue to be, subjected to physical and cyber-attacks, to date none have directly experienced a material breach or disruption to its network or information systems or our operations. However, as such attacks continue to increase in sophistication and frequency, the Registrants may be unable to prevent all such attacks in the future.
If a significant breach were to occur, the Registrants' reputation could be negatively affected, customer confidence in the Registrants or others in the industry could be diminished, or the Registrants could be subject to legal claims, loss of revenues, increased costs, or operations shutdown. Moreover, the amount and scope of insurance maintained against losses resulting from any such events or security breaches may not be sufficient to cover losses or otherwise adequately compensate for any disruptions to business that could result.
The Utility Registrants' deployment of smart meters throughout their service territories could increase the risk of damage from an intentional disruption of the system by third parties.
In addition, new or updated security regulations or unforeseen threat sources could require changes in current measures taken by the Registrants or their business operations and could adversely affect their consolidated financial statements.
ITEM 4. MINE SAFETY DISCLOSURES
All Registrants
Not applicable to the Registrants.FACTORS.
ITEM 5. OTHER INFORMATION
Amendments to Exelon Governing DocumentsAll Registrants
On August 3, 2022, Exelon adopted Amended and Restated Bylaws (the “Bylaws”), effective as of that date. Amendments contained in the Bylaws include the addition of language to amend Exelon's advance notice provisions to address the adoption by the Securities and Exchange Commission of universal proxy rules, reorganization of certain sections, and other minor edits to address certain administrative and other non-material matters.None.
ITEM 6. EXHIBITS
Certain of the following exhibits are incorporated herein by reference under Rule 12b-32 of the Securities and Exchange Act of 1934, as amended. Certain other instruments which would otherwise be required to be listed below have not been so listed because such instruments do not authorize securities in an amount which exceeds 10% of the total assets of the applicable Registrant and its subsidiaries on a consolidated basis and the relevant Registrant agrees to furnish a copy of any such instrument to the Commission upon request.
(4) Instruments Defining the Rights of Securities Holders, Including Indentures
| | | | | | | | | | | | | | | | | |
| Exelon Corporation | | | | |
| | | | | |
| Exhibit No. | Description | | Location |
| Sixth Supplemental Indenture, dated as of February 1, 2023, among Exelon Corporation and The Bank of New York Mellon Trust Company, N.A., as trustee | | |
| | | | | |
| Potomac Electric Power Company | | | | |
| | | | | |
| Exhibit No. | Description | | | |
| Supplemental Indenture to the Potomac Electric Power Company Mortgage and Deed of Trust, dated as of March 1, 2023 | | |
| | | | | |
| Delmarva Power & Light Company | | | | |
| | | | | |
| Exhibit No. | Description | | | |
| Supplemental Indenture to the Delmarva Power & Light Company Mortgage and Deed of Trust, dated as of March 1, 2023 | | |
| | | | | |
| Atlantic City Electric Company | | | | |
| | | | | |
| Exhibit No. | Description | | | |
| Supplemental Indenture to the Atlantic City Electric Company Mortgage and Deed of Trust, dated as of March 1, 2023 | | |
Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities and Exchange Act of 1934 as to the Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2023 filed by the following officers for the following companies:
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| Exelon Corporation |
| Exhibit No. | Description |
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Commonwealth Edison Company and U.S. Bank , N.A., as trustee (File 001-16844, Form 8-K dated May 24, 2022, |
Exhibit 4.1)No. | Description |
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| PECO Energy Company |
Exhibit 4.2)No. | Description |
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| Baltimore Gas and Electric Company |
| Exhibit No. | Description |
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| Pepco Holdings LLC |
| Exhibit No. | Description |
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| Potomac Electric Power Company |
| Exhibit No. | Description |
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| Delmarva Power & Light Company |
| Exhibit No. | Description |
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| Atlantic City Electric Company |
| Exhibit No. | Description |
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Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) as to the Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2023 filed by the following officers for the following companies:
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| Exelon Corporation |
| Exhibit No. | Description |
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| Commonwealth Edison Company |
| Exhibit No. | Description |
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| PECO Energy Company |
| Exhibit No. | Description |
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| Baltimore Gas and Electric Company |
| Exhibit No. | Description |
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| Pepco Holdings LLC |
| Exhibit No. | Description |
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| Potomac Electric Power Company |
| Exhibit No. | Description |
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| Delmarva Power & Light Company |
| Exhibit No. | Description |
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| Atlantic City Electric Company |
| Exhibit No. | Description |
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| 101.INS | Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document. |
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| 101.SCH | Inline XBRL Taxonomy Extension Schema Document.Document |
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| 101.CAL | Inline XBRL Taxonomy Extension Calculation Linkbase Document.Document |
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| 101.DEF | Inline XBRL Taxonomy Extension Definition Linkbase Document.Document |
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| 101.LAB | Inline XBRL Taxonomy Extension Labels Linkbase Document.Document |
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| 101.PRE | Inline XBRL Taxonomy Extension Presentation Linkbase Document.Document |
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| 104 | Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101) |
*Filed herewith
Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities and Exchange Act of 1934 as to the Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2022 filed by the following officers for the following companies:
Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes — Oxley Act of 2002) as to the Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2022 filed by the following officers for the following companies:
SIGNATURES
Pursuant to requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
EXELON CORPORATION
| | | | | | | | |
/s/ CHRISTOPHER M. CRANECALVIN G. BUTLER, JR. | | /s/ JOSEPH NIGROJEANNE M. JONES |
Christopher M. CraneCalvin G. Butler, Jr. | | Joseph NigroJeanne M. Jones |
President, Chief Executive Officer
(Principal Executive Officer) and Director | | Senior Executive Vice President and Chief Financial Officer
(Principal Financial Officer) |
| | |
| /s/ JOSEPH R. TRPIK | | |
| Joseph R. Trpik | | |
Senior Vice President and Corporate Controller
(Principal Accounting Officer) | | |
AugustMay 3, 20222023
Pursuant to requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
COMMONWEALTH EDISON COMPANY
| | | | | | | | |
| /s/ GIL C. QUINIONES | | /s/ ELISABETH J. GRAHAM |
| Gil C. Quiniones | | Elisabeth J. Graham |
Chief Executive Officer
(Principal Executive Officer) and Director | | Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer) |
| | |
| /s/ STEVEN J. CICHOCKI | | |
| Steven J. Cichocki | | |
Director, Accounting
(Principal Accounting Officer) | | |
AugustMay 3, 20222023
Pursuant to requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
PECO ENERGY COMPANY
| | | | | | | | |
| /s/ MICHAEL A. INNOCENZO | | /s/ ROBERT J. STEFANIMARISSA HUMPHREY |
| Michael A. Innocenzo | | Robert J. StefaniMarissa Humphrey |
President, and Chief Executive Officer
(Principal Executive Officer) and Director | | Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer) |
| | |
| /s/ CAROLINE FULGINITI | | |
| Caroline Fulginiti | | |
Director, Accounting
(Principal Accounting Officer) | | |
AugustMay 3, 20222023
Pursuant to requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
BALTIMORE GAS AND ELECTRIC COMPANY
| | | | | | | | |
| /s/ CARIM V. KHOUZAMI | | /s/ DAVID M. VAHOS |
| Carim V. Khouzami | | David M. Vahos |
President, Chief Executive Officer
(Principal Executive Officer) and Director | | Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer) |
| | |
| /s/ JASON T. JONES | | |
| Jason T. Jones | | |
Director, Accounting
(Principal Accounting Officer) | | |
AugustMay 3, 20222023
Pursuant to requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
PEPCO HOLDINGS LLC
| | | | | | | | |
| /s/ J. TYLER ANTHONY | | /s/ PHILLIP S. BARNETT |
| J. Tyler Anthony | | Phillip S. Barnett |
President, and Chief Executive Officer
(Principal Executive Officer) and Director | | Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer) |
| | |
| /s/ JULIE E. GIESE | | |
| Julie E. Giese | | |
Director, Accounting
(Principal Accounting Officer) | | |
AugustMay 3, 20222023
Pursuant to requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
POTOMAC ELECTRIC POWER COMPANY
| | | | | | | | |
| /s/ J. TYLER ANTHONY | | /s/ PHILLIP S. BARNETT |
| J. Tyler Anthony | | Phillip S. Barnett |
President, and Chief Executive Officer
(Principal Executive Officer) and Director | | Senior Vice President, Chief Financial Officer, and Treasurer
(Principal Financial Officer) and Director |
| | |
| /s/ JULIE E. GIESE | | |
| Julie E. Giese | | |
Director, Accounting
(Principal Accounting Officer) | | |
AugustMay 3, 20222023
Pursuant to requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
DELMARVA POWER & LIGHT COMPANY
| | | | | | | | |
| /s/ J. TYLER ANTHONY | | /s/ PHILLIP S. BARNETT |
| J. Tyler Anthony | | Phillip S. Barnett |
President, and Chief Executive Officer
(Principal Executive Officer) and Director | | Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer) |
| | |
| /s/ JULIE E. GIESE | | |
| Julie E. Giese | | |
Director, Accounting
(Principal Accounting Officer) | | |
AugustMay 3, 20222023
Pursuant to requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
ATLANTIC CITY ELECTRIC COMPANY
| | | | | | | | |
| /s/ J. TYLER ANTHONY | | /s/ PHILLIP S. BARNETT |
| J. Tyler Anthony | | Phillip S. Barnett |
President, and Chief Executive Officer
(Principal Executive Officer) and Director | | Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer) |
| | |
| /s/ JULIE E. GIESE | | |
| Julie E. Giese | | |
Director, Accounting
(Principal Accounting Officer) | | |
AugustMay 3, 20222023