0001109357exc:BaltimoreGasAndElectricCompanyMemberexc:ExelonGenerationCoLlcAffiliateMember2022-01-012022-03-310001109357exc:PotomacElectricPowerCoAffiliateMemberexc:DelmarvaPowerandLightCompanyMember2021-12-31PotomacElectricPowerCompanyMemberus-gaap:OperatingSegmentsMemberexc:AlternativeRevenueProgramsMemberus-gaap:RegulatedOperationMember2021-04-012021-06-30

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 March 31,June 30, 2022
or
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Commission File NumberName of Registrant; State or Other Jurisdiction of Incorporation; Address of Principal Executive Offices; and Telephone NumberIRS Employer Identification Number
001-16169EXELON CORPORATION23-2990190
(a Pennsylvania corporation)
10 South Dearborn Street
P.O. Box 805379
Chicago, Illinois 60680-5379
(800) 483-3220
001-01839COMMONWEALTH EDISON COMPANY36-0938600
(an Illinois corporation)
10 South Dearborn Street
49th Floor
Chicago, Illinois 60603-2300
(312) 394-4321
000-16844PECO ENERGY COMPANY23-0970240
(a Pennsylvania corporation)
P.O. Box 8699
2301 Market Street
Philadelphia, Pennsylvania 19101-8699
(215) 841-4000
001-01910BALTIMORE GAS AND ELECTRIC COMPANY52-0280210
(a Maryland corporation)
2 Center Plaza
110 West Fayette Street
Baltimore, Maryland 21201-3708
(410) 234-5000
001-31403PEPCO HOLDINGS LLC52-2297449
(a Delaware limited liability company)
701 Ninth Street, N.W.
Washington, District of Columbia 20068-0001
(202) 872-2000
001-01072POTOMAC ELECTRIC POWER COMPANY53-0127880
(a District of Columbia and Virginia corporation)
701 Ninth Street, N.W.
Washington, District of Columbia 20068-001
(202) 872-2000
001-01405DELMARVA POWER & LIGHT COMPANY51-0084283
(a Delaware and Virginia corporation)
500 North Wakefield Drive
Newark, Delaware 19702-5440
(202) 872-2000
001-03559ATLANTIC CITY ELECTRIC COMPANY21-0398280
(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 classTrading Symbol(s)Name of each exchange on which registered
EXELON CORPORATION:
Common stock, without par valueEXCThe 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 CompanyEXC/28New 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 CorporationLarge Accelerated FilerxAccelerated Filer☐Non-accelerated Filer☐Smaller Reporting Company☐Emerging Growth Company☐
Commonwealth Edison CompanyLarge Accelerated Filer☐Accelerated Filer☐Non-accelerated FilerxSmaller Reporting Company☐Emerging Growth Company☐
PECO Energy CompanyLarge Accelerated Filer☐Accelerated Filer☐Non-accelerated FilerxSmaller Reporting Company☐Emerging Growth Company☐
Baltimore Gas and Electric CompanyLarge Accelerated Filer☐Accelerated Filer☐Non-accelerated FilerxSmaller Reporting Company☐Emerging Growth Company☐
Pepco Holdings LLCLarge Accelerated Filer☐Accelerated Filer☐Non-accelerated FilerxSmaller Reporting Company☐Emerging Growth Company☐
Potomac Electric Power CompanyLarge Accelerated Filer☐Accelerated Filer☐Non-accelerated FilerxSmaller Reporting Company☐Emerging Growth Company☐
Delmarva Power & Light CompanyLarge Accelerated Filer☐Accelerated Filer☐Non-accelerated FilerxSmaller Reporting Company☐Emerging Growth Company☐
Atlantic City Electric CompanyLarge Accelerated Filer☐Accelerated Filer☐Non-accelerated FilerxSmaller 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 March 31,June 30, 2022 was:
Exelon Corporation Common Stock, without par value980,209,605980,472,436
Commonwealth Edison Company Common Stock, $12.50 par value127,021,391
PECO Energy Company Common Stock, without par value170,478,507
Baltimore Gas and Electric Company Common Stock, without par value1,000
Pepco Holdings LLCnot applicable
Potomac Electric Power Company Common Stock, $0.01 par value100
Delmarva Power & Light Company Common Stock, $2.25 par value1,000
Atlantic City Electric Company Common Stock, $3.00 par value8,546,017


TABLE OF CONTENTS
Page No.
4
7
7
7
8
8
Exelon Corporation
Consolidated Statements of Operations and Comprehensive Income
9
Consolidated Statements of Cash Flows
10
Consolidated Balance Sheets
11
Consolidated Statements of Changes in Shareholders’ Equity
13
Commonwealth Edison Company
Consolidated Statements of Operations and Comprehensive Income
1415
Consolidated Statements of Cash Flows
1516
Consolidated Balance Sheets
1617
Consolidated Statements of Changes in Shareholders' Equity
1819
PECO Energy Company
Consolidated Statements of Operations and Comprehensive Income
1920
Consolidated Statements of Cash Flows
2021
Consolidated Balance Sheets
2122
Consolidated Statements of Changes in Shareholder's Equity
2324
Baltimore Gas and Electric Company
Statements of Operations and Comprehensive Income
2425
Statements of Cash Flows
2526
Balance Sheets
2627
Statements of Changes in Shareholder's Equity
2829
Pepco Holdings LLC
Consolidated Statements of Operations and Comprehensive Income
2930
Consolidated Statements of Cash Flows
3031
Consolidated Balance Sheets
3132
Consolidated Statements of Changes in Member's Equity
3334
1




Page No.
Potomac Electric Power Company
Statements of Operations and Comprehensive Income
3435
Statements of Cash Flows
3536
Balance Sheets
3637
Statements of Changes in Shareholder's Equity
3839
Delmarva Power & Light Company
Statements of Operations and Comprehensive Income
3940
Statements of Cash Flows
4041
Balance Sheets
4142
Statements of Changes in Shareholder’s Equity
4344
Atlantic City Electric Company
Consolidated Statements of Operations and Comprehensive Income
4445
Consolidated Statements of Cash Flows
4546
Consolidated Balance Sheets
4647
Consolidated Statements of Changes in Shareholder’s Equity
4849
Combined Notes to Consolidated Financial Statements
1. Significant Accounting Policies
4950
2. Discontinued Operations
5051
3. Regulatory Matters
5556
4. Revenue from Contracts with Customers
5860
5. Segment Information
5962
6. Accounts Receivable
6471
7. Income Taxes
6674
8. Retirement Benefits
6877
9. Derivative Financial Instruments
7281
10. Debt and Credit Agreements
7483
11. Fair Value of Financial Assets and Liabilities
7786
12. Commitments and Contingencies
8392
13. Changes in Accumulated Other Comprehensive Income
9099
14. Supplemental Financial Information
90100
15. Related Party Transactions
95105
2




Page No.
99109
Exelon Corporation
99109
Executive Overview
99109
Financial Results of Operations
99109
Significant 2022 Transactions and Developments
101112
Other Key Business Drivers and Management Strategies
103115
Critical Accounting Policies and Estimates
103115
Results of Operations By Registrant
104116
Commonwealth Edison Company
104116
PECO Energy Company
107119
Baltimore Gas and Electric Company
111123
Pepco Holdings LLC
114126
Potomac Electric Power Company
115127
Delmarva Power & Light Company
118130
Atlantic City Electric Company
122134
Liquidity and Capital Resources
125138
133146
134147
134147
134147
134147
134148
135148
135149
138152
138152
139153
140154
141155
142156
143157
144158
145159
3



Table of Contents
GLOSSARY OF TERMS AND ABBREVIATIONS
Exelon Corporation and Related Entities
ExelonExelon Corporation
ComEdCommonwealth Edison Company
PECOPECO Energy Company
BGEBaltimore Gas and Electric Company
Pepco Holdings or PHIPepco Holdings LLC
PepcoPotomac Electric Power Company
DPLDelmarva Power & Light Company
ACEAtlantic City Electric Company
RegistrantsExelon, ComEd, PECO, BGE, PHI, Pepco, DPL, and ACE, collectively
Utility RegistrantsComEd, PECO, BGE, Pepco, DPL, and ACE, collectively
ACE Funding or ATFAtlantic City Electric Transition Funding LLC
BSCExelon Business Services Company, LLC
Exelon CorporateExelon in its corporate capacity as a holding company
PCIPotomac Capital Investment Corporation and its subsidiaries
PECO Trust IIIPECO Energy Capital Trust III
PECO Trust IVPECO Energy Capital Trust IV
PHI CorporatePHI in its corporate capacity as a holding company
PHISCOPHI Service Company
Former Related Entities
ConstellationConstellation Energy Corporation
GenerationConstellation Energy Generation, LLC (formerly Exelon Generation Company, LLC, a subsidiary of Exelon prior to separation on February 1, 2022)
4



Table of Contents
GLOSSARY OF TERMS AND ABBREVIATIONS
Other Terms and Abbreviations
2021 Form 10-KThe 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-KThe 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 Recast Form 10-KReference to specific Combined Note to Consolidated Financial Statements within Exelon'sin the 2021 Annual Report onRecast Form 10-K
AECAlternative Energy Credit that is issued for each megawatt hour of generation from a qualified alternative energy source
AFUDCAllowance for Funds Used During Construction
AMIAdvanced Metering Infrastructure
AOCIAccumulated Other Comprehensive Income (Loss)
AROAsset Retirement Obligation
BGSBasic Generation Service
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
CERCLAComprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended
CIPConservation Incentive Program
CMCCarbon Mitigation Credit
CODMChief Operating Decision Maker(s)
DC PLUGDistrict of Columbia Power Line Undergrounding Initiative
DCPSCPublic Service Commission of the District of Columbia
DEPSCDelaware Public Service Commission
DOEEDistrict of Columbia Department of Energy & Environment
DPPDeferred Purchase Price
EIMAEnergy Infrastructure Modernization Act (Illinois Senate Bill 1652 and Illinois House Bill 3036)
EPAUnited States Environmental Protection Agency
ERCOTElectric Reliability Council of Texas
ERISAEmployee Retirement Income Security Act of 1974, as amended
ETACEnergy Transition Assistance Charge
FEJAIllinois Public Act 99-0906 or Future Energy Jobs Act
FERCFederal Energy Regulatory Commission
GAAPGenerally Accepted Accounting Principles in the United States
GCRGas Cost Rate
GSAGeneration Supply Adjustment
GWhGigawatt hour
ICCIllinois Commerce Commission
Illinois Settlement LegislationLegislation enacted in 2007 affecting electric utilities in Illinois
IPAIllinois Power Agency
IRCInternal Revenue Code
IRSInternal Revenue Service
LIBORLondon Interbank Offered Rate
MDPSCMaryland Public Service Commission
MGPManufactured Gas Plant
mmcfMillion Cubic Feet
MWMegawatt
MWhMegawatt hour
N/ANot applicable
NDTNuclear Decommissioning Trust
NJBPUNew Jersey Board of Public Utilities
NPNSNormal Purchase Normal Sale scope exception
5



Table of Contents
GLOSSARY OF TERMS AND ABBREVIATIONS
Other Terms and Abbreviations
MWMegawatt
MWhMegawatt hour
N/ANot applicable
NDTNuclear Decommissioning Trust
NJBPUNew Jersey Board of Public Utilities
NPNSNormal Purchase Normal Sale scope exception
NPSNational Park Service
OCIOther Comprehensive Income
OPEBOther Postretirement Employee Benefits
PAPUCPennsylvania Public Utility Commission
PGCPurchased Gas Cost Clause
PJMPJM Interconnection, LLC
POLRProvider of Last Resort
PPAPower Purchase Agreement
PP&EProperty, plant, and equipment
PRPPotentially Responsible Parties
RECRenewable Energy Credit which is issued for each megawatt hour of generation from a qualified renewable energy source
Regulatory Agreement UnitsNuclear generating units or portions thereof whose decommissioning-related activities are subject to contractual elimination under regulatory accounting
RFPRequest for Proposal
RiderReconcilable Surcharge Recovery Mechanism
ROEReturn on equity
ROURight-of-use
RPSRenewable Energy Portfolio Standards
RTORegional Transmission Organization
SECUnited States Securities and Exchange Commission
SOFRSecured Overnight Financing Rate
SOSStandard Offer Service
STRIDEMaryland Strategic Infrastructure Development and Enhancement Program
TCJATax Cuts and Jobs Act
Transition BondsTransition Bonds issued by ACE Funding
ZECZero Emission Credit or Zero Emission Certificate
6



Table of Contents
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,” 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 Registrants' combined 2021 Annual Report on Form 10-K in (a) Part I, ITEM 1A. Risk Factors, (b)Factors; (2) the 2021 Recast Form 10-K in (a) Part II, ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations and (c)(b) Part II, ITEM 8. Financial Statements and Supplementary Data: Note 19,17, Commitments and Contingencies; (2)(3) 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 (3)(4) 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.
7



Table of Contents
PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
8



Table of Contents

EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
Three Months Ended
March 31,		Three Months Ended
June 30,		Six Months Ended
June 30,
(In millions, except per share data)(In millions, except per share data)20222021(In millions, except per share data)2022202120222021
Operating revenuesOperating revenuesOperating revenues
Electric operating revenuesElectric operating revenues$4,481 $3,870 Electric operating revenues$3,934 $3,739 $8,415 $7,609 
Natural gas operating revenuesNatural gas operating revenues817 633 Natural gas operating revenues307 234 1,124 867 
Revenues from alternative revenue programsRevenues from alternative revenue programs29 129 Revenues from alternative revenue programs(2)47 27 176 
Total operating revenuesTotal operating revenues5,327 4,632 Total operating revenues4,239 4,020 9,566 8,652 
Operating expensesOperating expensesOperating expenses
Purchased powerPurchased power1,581 1,140 Purchased power1,167 1,006 2,748 2,146 
Purchased fuelPurchased fuel338 218 Purchased fuel107 58 445 276 
Purchased power and fuel from affiliatesPurchased power and fuel from affiliates159 293 Purchased power and fuel from affiliates— 257 159 550 
Operating and maintenanceOperating and maintenance1,178 1,083 Operating and maintenance1,109 1,073 2,288 2,155 
Depreciation and amortizationDepreciation and amortization817 757 Depreciation and amortization830 736 1,647 1,494 
Taxes other than income taxesTaxes other than income taxes354 317 Taxes other than income taxes330 314 684 631 
Total operating expensesTotal operating expenses4,427 3,808 Total operating expenses3,543 3,444 7,971 7,252 
(Loss) gain on sales of assets and businesses(Loss) gain on sales of assets and businesses(2)4 (2)4 
Operating incomeOperating income900 824 Operating income694 580 1,593 1,404 
Other income and (deductions)Other income and (deductions)Other income and (deductions)
Interest expense, netInterest expense, net(332)(312)Interest expense, net(352)(318)(684)(630)
Interest expense to affiliatesInterest expense to affiliates(6)(6)Interest expense to affiliates(6)(6)(13)(13)
Other, netOther, net137 58 Other, net175 73 313 131 
Total other deductions(201)(260)
Total other income and (deductions)Total other income and (deductions)(183)(251)(384)(512)
Income from continuing operations before income taxesIncome from continuing operations before income taxes699 564 Income from continuing operations before income taxes511 329 1,209 892 
Income taxesIncome taxes218 39 Income taxes46 3 263 42 
Equity in earnings of unconsolidated affiliatesEquity in earnings of unconsolidated affiliates— — — 1 
Net income from continuing operations after income taxesNet income from continuing operations after income taxes481 525 Net income from continuing operations after income taxes465 326 946 851 
Net income (loss) from discontinued operations after income taxes (Note 2)Net income (loss) from discontinued operations after income taxes (Note 2)117 (789)Net income (loss) from discontinued operations after income taxes (Note 2)— 150 117 (640)
Net income (loss)598 (264)
Net incomeNet income465 476 1,063 211 
Net income attributable to noncontrolling interestsNet income attributable to noncontrolling interests1 25 Net income attributable to noncontrolling interests— 75 1 99 
Net income (loss) attributable to common shareholders$597 $(289)
Net income attributable to common shareholdersNet income attributable to common shareholders$465 $401 $1,062 $112 
Amounts attributable to common shareholders:Amounts attributable to common shareholders:Amounts attributable to common shareholders:
Net income from continuing operationsNet income from continuing operations481 525 Net income from continuing operations465 326 946 851 
Net income (loss) from discontinued operationsNet income (loss) from discontinued operations116 (814)Net income (loss) from discontinued operations— 75 116 (739)
Net income (loss) attributable to common shareholders$597 $(289)
Net income attributable to common shareholdersNet income attributable to common shareholders$465 $401 $1,062 $112 
Comprehensive income (loss), net of income taxes
Net income (loss)$598 $(264)
Comprehensive income, net of income taxesComprehensive income, net of income taxes
Net incomeNet income$465 $476 $1,063 $211 
Other comprehensive income (loss), net of income taxesOther comprehensive income (loss), net of income taxesOther comprehensive income (loss), net of income taxes
Pension and non-pension postretirement benefit plans:Pension and non-pension postretirement benefit plans:Pension and non-pension postretirement benefit plans:
Prior service benefit reclassified to periodic benefit costPrior service benefit reclassified to periodic benefit cost— (1)Prior service benefit reclassified to periodic benefit cost2 (1)2 (2)
Actuarial loss reclassified to periodic benefit costActuarial loss reclassified to periodic benefit cost14 56 Actuarial loss reclassified to periodic benefit cost10 56 24 112 
Pension and non-pension postretirement benefit plan valuation adjustmentPension and non-pension postretirement benefit plan valuation adjustment— (2)Pension and non-pension postretirement benefit plan valuation adjustment— — — (2)
Unrealized gain on foreign currency translationUnrealized gain on foreign currency translation— 1 Unrealized gain on foreign currency translation— 2 — 3 
Other comprehensive incomeOther comprehensive income14 54 Other comprehensive income12 57 26 111 
Comprehensive income (loss)612 (210)
Comprehensive incomeComprehensive income477 533 1,089 322 
Comprehensive income attributable to noncontrolling interestsComprehensive income attributable to noncontrolling interests1 25 Comprehensive income attributable to noncontrolling interests— 75 1 99 
Comprehensive income (loss) attributable to common shareholders$611 $(235)
Comprehensive income attributable to common shareholdersComprehensive income attributable to common shareholders$477 $458 $1,088 $223 
Average shares of common stock outstanding:Average shares of common stock outstanding:Average shares of common stock outstanding:
BasicBasic981 977 Basic981 978 981 978 
Assumed exercise and/or distributions of stock-based awardsAssumed exercise and/or distributions of stock-based awards— 1 Assumed exercise and/or distributions of stock-based awards1 1 1 1 
Diluted(a)
Diluted(a)
981 978 
Diluted(a)
982 979 982 979 
Earnings per average common share from continuing operationsEarnings per average common share from continuing operationsEarnings per average common share from continuing operations
BasicBasic$0.49 $0.53 Basic$0.47 $0.33 $0.96 $0.87 
DilutedDiluted$0.49 $0.53 Diluted$0.47 $0.33 $0.96 $0.87 
Earnings (losses) per average common share from discontinued operationsEarnings (losses) per average common share from discontinued operationsEarnings (losses) per average common share from discontinued operations
BasicBasic$0.12 $(0.83)Basic$— $0.08 $0.12 $(0.76)
DilutedDiluted$0.12 $(0.83)Diluted$— $0.08 $0.12 $(0.76)
__________
(a)The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect were none and less than 1 million for the three and six months ended March 31,June 30, 2022 and 2021, respectively.
See the Combined Notes to Consolidated Financial Statements
9



Table of Contents

EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
Three Months Ended
March 31,		Six Months Ended
June 30,
(In millions)(In millions)20222021(In millions)20222021
Cash flows from operating activitiesCash flows from operating activitiesCash flows from operating activities
Net income (loss)$598 $(264)
Net incomeNet income$1,063 $211 
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 amortizationDepreciation, amortization, and accretion, including nuclear fuel and energy contract amortization1,024 2,104 Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization1,854 4,180 
Asset impairmentsAsset impairments— 1 Asset impairments— 500 
Gain on sales of assets and businessesGain on sales of assets and businesses(10)(71)Gain on sales of assets and businesses(8)(83)
Deferred income taxes and amortization of investment tax creditsDeferred income taxes and amortization of investment tax credits110 (142)Deferred income taxes and amortization of investment tax credits143 (163)
Net fair value changes related to derivativesNet fair value changes related to derivatives(59)(178)Net fair value changes related to derivatives(59)(490)
Net realized and unrealized losses (gains) on NDT fundsNet realized and unrealized losses (gains) on NDT funds205 (118)Net realized and unrealized losses (gains) on NDT funds205 (376)
Net unrealized losses on equity investments16 23 
Net unrealized losses (gains) on equity investmentsNet unrealized losses (gains) on equity investments16 (96)
Other non-cash operating activitiesOther non-cash operating activities232 (170)Other non-cash operating activities276 (331)
Changes in assets and liabilities:Changes in assets and liabilities:Changes in assets and liabilities:
Accounts receivableAccounts receivable(711)(372)Accounts receivable(795)(16)
InventoriesInventories125 77 Inventories12 1 
Accounts payable and accrued expensesAccounts payable and accrued expenses291 (176)Accounts payable and accrued expenses544 (87)
Option premiums (paid) received, netOption premiums (paid) received, net(39)16 Option premiums (paid) received, net(39)2 
Collateral received, netCollateral received, net1,142 273 Collateral received, net1,689 957 
Income taxesIncome taxes77 113 Income taxes23 190 
Regulatory assets and liabilities, netRegulatory assets and liabilities, net(376)(276)
Pension and non-pension postretirement benefit contributionsPension and non-pension postretirement benefit contributions(574)(537)Pension and non-pension postretirement benefit contributions(585)(559)
Other assets and liabilitiesOther assets and liabilities(645)(1,840)Other assets and liabilities(723)(2,426)
Net cash flows provided by (used in) operating activities1,782 (1,261)
Net cash flows provided by operating activitiesNet cash flows provided by operating activities3,240 1,138 
Cash flows from investing activitiesCash flows from investing activitiesCash flows from investing activities
Capital expendituresCapital expenditures(1,922)(2,140)Capital expenditures(3,507)(4,040)
Proceeds from NDT fund salesProceeds from NDT fund sales488 2,908 Proceeds from NDT fund sales488 4,438 
Investment in NDT fundsInvestment in NDT funds(516)(2,939)Investment in NDT funds(516)(4,538)
Collection of DPPCollection of DPP169 1,574 Collection of DPP169 2,209 
Proceeds from sales of assets and businessesProceeds from sales of assets and businesses16 680 Proceeds from sales of assets and businesses16 724 
Other investing activitiesOther investing activities(54)12 Other investing activities4 17 
Net cash flows (used in) provided by investing activities(1,819)95 
Net cash flows used in investing activitiesNet cash flows used in investing activities(3,346)(1,190)
Cash flows from financing activitiesCash flows from financing activitiesCash flows from financing activities
Changes in short-term borrowingsChanges in short-term borrowings(700)597 Changes in short-term borrowings(597)(666)
Proceeds from short-term borrowings with maturities greater than 90 daysProceeds from short-term borrowings with maturities greater than 90 days1,150 500 Proceeds from short-term borrowings with maturities greater than 90 days1,150 500 
Repayments on short-term borrowings with maturities greater than 90 daysRepayments on short-term borrowings with maturities greater than 90 days(350)— Repayments on short-term borrowings with maturities greater than 90 days(350)— 
Issuance of long-term debtIssuance of long-term debt4,301 1,705 Issuance of long-term debt5,151 2,455 
Retirement of long-term debtRetirement of long-term debt(6)(79)Retirement of long-term debt(1,707)(630)
Dividends paid on common stockDividends paid on common stock(332)(374)Dividends paid on common stock(663)(747)
Proceeds from employee stock plansProceeds from employee stock plans9 31 Proceeds from employee stock plans17 47 
Transfer of cash, restricted cash, and cash equivalents to ConstellationTransfer 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 activitiesOther financing activities(62)(46)Other financing activities(84)(64)
Net cash flows provided by financing activitiesNet cash flows provided by financing activities1,416 2,334 Net cash flows provided by financing activities323 895 
Increase in cash, restricted cash, and cash equivalentsIncrease in cash, restricted cash, and cash equivalents1,379 1,168 Increase in cash, restricted cash, and cash equivalents217 843 
Cash, restricted cash, and cash equivalents at beginning of periodCash, restricted cash, and cash equivalents at beginning of period1,619 1,166 Cash, restricted cash, and cash equivalents at beginning of period1,619 1,166 
Cash, restricted cash, and cash equivalents at end of periodCash, restricted cash, and cash equivalents at end of period$2,998 $2,334 Cash, restricted cash, and cash equivalents at end of period$1,836 $2,009 
Supplemental cash flow informationSupplemental cash flow informationSupplemental cash flow information
Decrease in capital expenditures not paidDecrease in capital expenditures not paid$(322)$(324)Decrease in capital expenditures not paid$(276)$(313)
Increase in DPPIncrease in DPP348 1,339 Increase in DPP348 1,958 
(Decrease) increase in PP&E related to ARO update(Decrease) increase in PP&E related to ARO update(335)2 (Decrease) increase in PP&E related to ARO update(335)2 
See the Combined Notes to Consolidated Financial Statements
10



Table of Contents
EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)(In millions)March 31, 2022December 31, 2021(In millions)June 30, 2022December 31, 2021
ASSETSASSETSASSETS
Current assetsCurrent assetsCurrent assets
Cash and cash equivalentsCash and cash equivalents$2,476 $672 Cash and cash equivalents$816 $672 
Restricted cash and cash equivalentsRestricted cash and cash equivalents430 321 Restricted cash and cash equivalents961 321 
Accounts receivableAccounts receivableAccounts receivable
Customer accounts receivableCustomer accounts receivable2,3652,189Customer accounts receivable2,2192,189
Customer allowance for credit lossesCustomer allowance for credit losses(389)(320)Customer allowance for credit losses(354)(320)
Customer accounts receivable, netCustomer accounts receivable, net1,976 1,869 Customer accounts receivable, net1,865 1,869 
Other accounts receivableOther accounts receivable1,1481,068Other accounts receivable1,4031,068
Other allowance for credit lossesOther allowance for credit losses(81)(72)Other allowance for credit losses(81)(72)
Other accounts receivable, netOther accounts receivable, net1,067 996 Other accounts receivable, net1,322 996 
Inventories, netInventories, netInventories, net
Fossil fuel and emission allowances39 105 
Fossil fuelFossil fuel133 105 
Materials and suppliesMaterials and supplies473 476 Materials and supplies491 476 
Regulatory assetsRegulatory assets1,221 1,296 Regulatory assets1,239 1,296 
OtherOther463 387 Other515 387 
Current assets of discontinued operationsCurrent assets of discontinued operations— 7,835 Current assets of discontinued operations— 7,835 
Total current assetsTotal current assets8,145 13,957 Total current assets7,342 13,957 
Property, plant, and equipment (net of accumulated depreciation and amortization of $14,878 and $14,430 as of March 31, 2022 and December 31, 2021, respectively)65,465 64,558 
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)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 
Deferred debits and other assetsDeferred debits and other assetsDeferred debits and other assets
Regulatory assetsRegulatory assets8,200 8,224 Regulatory assets8,350 8,224 
Investments244 250 
GoodwillGoodwill6,630 6,630 Goodwill6,630 6,630 
Receivable related to Regulatory Agreement UnitsReceivable related to Regulatory Agreement Units2,969 — Receivable related to Regulatory Agreement Units2,265 — 
InvestmentsInvestments235 250 
OtherOther1,045 885 Other1,017 885 
Property, plant, and equipment, deferred debits, and other assets of discontinued operationsProperty, plant, and equipment, deferred debits, and other assets of discontinued operations— 38,509 Property, plant, and equipment, deferred debits, and other assets of discontinued operations— 38,509 
Total deferred debits and other assetsTotal deferred debits and other assets19,088 54,498 Total deferred debits and other assets18,497 54,498 
Total assetsTotal assets$92,698 $133,013 Total assets$92,295 $133,013 
See the Combined Notes to Consolidated Financial Statements
11



Table of Contents
EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)(In millions)March 31, 2022December 31, 2021(In millions)June 30, 2022December 31, 2021
LIABILITIES AND SHAREHOLDERS’ EQUITYLIABILITIES AND SHAREHOLDERS’ EQUITYLIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilitiesCurrent liabilitiesCurrent liabilities
Short-term borrowingsShort-term borrowings$1,900 $1,248 Short-term borrowings$2,003 $1,248 
Long-term debt due within one yearLong-term debt due within one year2,154 2,153 Long-term debt due within one year505 2,153 
Accounts payableAccounts payable2,175 2,379 Accounts payable2,451 2,379 
Accrued expensesAccrued expenses1,029 1,137 Accrued expenses1,057 1,137 
Payables to affiliatesPayables to affiliates6 5 Payables to affiliates5 5 
Regulatory liabilitiesRegulatory liabilities394 376 Regulatory liabilities411 376 
Mark-to-market derivative liabilitiesMark-to-market derivative liabilities— 18 Mark-to-market derivative liabilities— 18 
Unamortized energy contract liabilitiesUnamortized energy contract liabilities13 89 Unamortized energy contract liabilities11 89 
OtherOther964 766 Other1,588 766 
Current liabilities of discontinued operationsCurrent liabilities of discontinued operations— 7,940 Current liabilities of discontinued operations— 7,940 
Total current liabilitiesTotal current liabilities8,635 16,111 Total current liabilities8,031 16,111 
Long-term debtLong-term debt35,008 30,749 Long-term debt35,789 30,749 
Long-term debt to financing trustsLong-term debt to financing trusts390 390 Long-term debt to financing trusts390 390 
Deferred credits and other liabilitiesDeferred credits and other liabilitiesDeferred credits and other liabilities
Deferred income taxes and unamortized investment tax creditsDeferred income taxes and unamortized investment tax credits11,089 10,611 Deferred income taxes and unamortized investment tax credits11,240 10,611 
Asset retirement obligations273 271 
Regulatory liabilitiesRegulatory liabilities8,513 9,628 
Pension obligationsPension obligations1,447 2,051 Pension obligations1,406 2,051 
Non-pension postretirement benefit obligationsNon-pension postretirement benefit obligations800 811 Non-pension postretirement benefit obligations800 811 
Regulatory liabilities9,192 9,628 
Asset retirement obligationsAsset retirement obligations275 271 
Mark-to-market derivative liabilitiesMark-to-market derivative liabilities144 201 Mark-to-market derivative liabilities103 201 
Unamortized energy contract liabilitiesUnamortized energy contract liabilities42 146 Unamortized energy contract liabilities38 146 
OtherOther2,187 1,573 Other2,054 1,573 
Long-term debt, deferred credits, and other liabilities of discontinued operationsLong-term debt, deferred credits, and other liabilities of discontinued operations— 25,676 Long-term debt, deferred credits, and other liabilities of discontinued operations— 25,676 
Total deferred credits and other liabilitiesTotal deferred credits and other liabilities25,174 50,968 Total deferred credits and other liabilities24,429 50,968 
Total liabilitiesTotal liabilities69,207 98,218 Total liabilities68,639 98,218 
Commitments and contingenciesCommitments and contingencies00Commitments and contingencies00
Shareholders’ equityShareholders’ equityShareholders’ equity
Common stock (No par value, 2,000 shares authorized, 980 shares and 979 shares outstanding at March 31, 2022 and December 31, 2021, respectively)20,299 20,324 
Treasury stock, at cost (2 shares at March 31, 2022 and December 31, 2021)(123)(123)
Common stock (No par value, 2,000 shares authorized, 980 shares and 979 shares outstanding at June 30, 2022 and December 31, 2021, respectively)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)Treasury stock, at cost (2 shares at June 30, 2022 and December 31, 2021)(123)(123)
Retained earningsRetained earnings4,028 16,942 Retained earnings4,161 16,942 
Accumulated other comprehensive loss, netAccumulated other comprehensive loss, net(713)(2,750)Accumulated other comprehensive loss, net(701)(2,750)
Total shareholders’ equityTotal shareholders’ equity23,491 34,393 Total shareholders’ equity23,656 34,393 
Noncontrolling interestsNoncontrolling interests— 402 Noncontrolling interests— 402 
Total equityTotal equity23,491 34,795 Total equity23,656 34,795 
Total liabilities and shareholders’ equityTotal liabilities and shareholders’ equity$92,698 $133,013 Total liabilities and shareholders’ equity$92,295 $133,013 

See the Combined Notes to Consolidated Financial Statements
12



Table of Contents
EXELON CORPORATION AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY
(Unaudited)
Three Months Ended March 31, 2022Six Months Ended June 30, 2022
(In millions, shares
in thousands)		(In millions, shares
in thousands)		Issued
Shares		Common
Stock		Treasury
Stock		Retained
Earnings		Accumulated
Other
Comprehensive
Loss, net		Noncontrolling
Interests		Total Shareholders'
Equity		(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, 2021Balance, December 31, 2021981,291 $20,324 $(123)$16,942 $(2,750)$402 $34,795 Balance, December 31, 2021981,291 $20,324 $(123)$16,942 $(2,750)$402 $34,795 
Net incomeNet income— — — 597 — 1 598 Net income— — — 597 — 1 598 
Long-term incentive plan activityLong-term incentive plan activity540 (13)— — — — (13)Long-term incentive plan activity540 (13)— — — — (13)
Employee stock purchase plan issuancesEmployee stock purchase plan issuances211 9 — — — — 9 Employee stock purchase plan issuances211 9 — — — — 9 
Changes in equity of noncontrolling interestsChanges in equity of noncontrolling interests— — — — — (7)(7)Changes in equity of noncontrolling interests— — — — — (7)(7)
Distribution of Constellation (Note 2)Distribution of Constellation (Note 2)— (21)— (13,179)2,023 (396)(11,573)Distribution of Constellation (Note 2)— (21)— (13,179)2,023 (396)(11,573)
Common stock dividends
($0.34/common share)
Common stock dividends
($0.34/common share)
— — — (332)— — (332)
Common stock dividends
($0.34/common share)
— — — (332)— — (332)
Other comprehensive income, net of income taxesOther comprehensive income, net of income taxes— — — — 14 — 14 Other comprehensive income, net of income taxes— — — — 14 — 14 
Balance, March 31, 2022Balance, March 31, 2022982,042 $20,299 $(123)$4,028 $(713)$— $23,491 Balance, March 31, 2022982,042 $20,299 $(123)$4,028 $(713)$— $23,491 
Net incomeNet income— — — 465 — — 465 
Long-term incentive plan activityLong-term incentive plan activity21 10 — — — — 10 
Employee stock purchase plan issuancesEmployee stock purchase plan issuances242 10 — — — — 10 
Changes in equity of noncontrolling interestsChanges in equity of noncontrolling interests— — — — — — — 
Common stock dividends
($0.34/common share)
Common stock dividends
($0.34/common share)
— — — (332)— — (332)
Other comprehensive income, net of income taxesOther comprehensive income, net of income taxes— — — — 12 — 12 
Balance, June 30, 2022Balance, June 30, 2022982,305 $20,319 $(123)$4,161 $(701)$— $23,656 

Three Months Ended March 31, 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, 2020977,466 $19,373 $(123)$16,735 $(3,400)$2,283 $34,868 
Net (loss) income— — — (289)— 25 (264)
Long-term incentive plan activity640 5 — — — — 5 
Employee stock purchase plan issuances902 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, 2021979,008 $19,412 $(123)$16,072 $(3,346)$2,298 $34,313 




















See the Combined Notes to Consolidated Financial Statements
13



Table of Contents
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, 2020977,466 $19,373 $(123)$16,735 $(3,400)$2,283 $34,868 
Net (loss) income— — — (289)— 25 (264)
Long-term incentive plan activity640 5 — — — — 5 
Employee stock purchase plan issuances902 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, 2021979,008 $19,412 $(123)$16,072 $(3,346)$2,298 $34,313 
Net income— — — 401 — 75 476 
Long-term incentive plan activity237 24 — — — — 24 
Employee stock purchase plan issuances420 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, 2021979,665 $19,454 $(123)$16,098 $(3,289)$2,360 $34,500 

See the Combined Notes to Consolidated Financial Statements
14



Table of Contents
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Operating revenues
Electric operating revenues$1,688 $1,475 
Revenues from alternative revenue programs40 54 
Operating revenues from affiliates6 6 
Total operating revenues1,734 1,535 
Operating expenses
Purchased power579 442 
Purchased power from affiliate59 85 
Operating and maintenance266 245 
Operating and maintenance from affiliates85 71 
Depreciation and amortization321 292 
Taxes other than income taxes96 75 
Total operating expenses1,406 1,210 
Operating income328 325 
Other income and (deductions)
Interest expense, net(97)(93)
Interest expense to affiliates(3)(3)
Other, net12 7 
Total other income and (deductions)(88)(89)
Income before income taxes240 236 
Income taxes52 39 
Net income$188 $197 
Comprehensive income$188 $197 

See the Combined Notes to Consolidated Financial Statements
14



Table of Contents
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Cash flows from operating activities
Net income$188 $197 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization321 292 
Deferred income taxes and amortization of investment tax credits54 63 
Other non-cash operating activities(9)(9)
Changes in assets and liabilities:
Accounts receivable(45)23 
Receivables from and payables to affiliates, net(42)(15)
Inventories3 (1)
Accounts payable and accrued expenses(154)(176)
Collateral received, net43 5 
Income taxes(2)(23)
Pension and non-pension postretirement benefit contributions(176)(171)
Other assets and liabilities(37)(159)
Net cash flows provided by operating activities144 26 
Cash flows from investing activities
Capital expenditures(617)(613)
Other investing activities7 7 
Net cash flows used in investing activities(610)(606)
Cash flows from financing activities
Changes in short-term borrowings— (188)
Issuance of long-term debt750 700 
Dividends paid on common stock(144)(127)
Contributions from parent167 198 
Other financing activities(10)(9)
Net cash flows provided by financing activities763 574 
Increase (decrease) in cash, restricted cash, and cash equivalents297 (6)
Cash, restricted cash, and cash equivalents at beginning of period384 405 
Cash, restricted cash, and cash equivalents at end of period$681 $399 
Supplemental cash flow information
Decrease in capital expenditures not paid$(50)$(107)
See the Combined Notes to Consolidated Financial Statements
15



Table of Contents
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)2022202120222021
Operating revenues
Electric operating revenues$1,387 $1,503 $3,075 $2,977 
Revenues from alternative revenue programs35 9 75 64 
Operating revenues from affiliates3 5 8 11 
Total operating revenues1,425 1,517 3,158 3,052 
Operating expenses
Purchased power283 421 862 862 
Purchased power from affiliate— 79 59 163 
Operating and maintenance258 250 523 495 
Operating and maintenance from affiliates80 73 166 144 
Depreciation and amortization328 296 649 589 
Taxes other than income taxes90 77 185 153 
Total operating expenses1,039 1,196 2,444 2,406 
Loss on sales of assets(2)— (2)— 
Operating income384 321 712 646 
Other income and (deductions)
Interest expense, net(101)(95)(197)(187)
Interest expense to affiliates(3)(3)(7)(6)
Other, net13 15 26 22 
Total other income and (deductions)(91)(83)(178)(171)
Income before income taxes293 238 534 475 
Income taxes66 46 119 85 
Net income$227 $192 $415 $390 
Comprehensive income$227 $192 $415 $390 

See the Combined Notes to Consolidated Financial Statements
15



Table of Contents
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
Six Months Ended
June 30,
(In millions)20222021
Cash flows from operating activities
Net income$415 $390 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization649 589 
Deferred income taxes and amortization of investment tax credits122 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 expenses123 (45)
Collateral received, net60 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 activities588 558 
Cash flows from investing activities
Capital expenditures(1,208)(1,162)
Other investing activities15 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 debt750 700 
Dividends paid on common stock(289)(253)
Contributions from parent335 395 
Other financing activities(12)(11)
Net cash flows provided by financing activities784 541 
Increase (decrease) in cash, restricted cash, and cash equivalents179 (51)
Cash, restricted cash, and cash equivalents at beginning of period384 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



Table of Contents
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)(In millions)March 31, 2022December 31, 2021(In millions)June 30, 2022December 31, 2021
ASSETSASSETSASSETS
Current assetsCurrent assetsCurrent assets
Cash and cash equivalents Cash and cash equivalents$343 $131  Cash and cash equivalents$120 $131 
Restricted cash and cash equivalents Restricted cash and cash equivalents246 210  Restricted cash and cash equivalents384 210 
Accounts receivable Accounts receivable Accounts receivable
Customer accounts receivable Customer accounts receivable702647 Customer accounts receivable589647
Customer allowance for credit losses Customer allowance for credit losses(92)(73) Customer allowance for credit losses(81)(73)
Customer accounts receivable, net Customer accounts receivable, net610 574  Customer accounts receivable, net508 574 
Other accounts receivable Other accounts receivable219227 Other accounts receivable448227
Other allowance for credit losses Other allowance for credit losses(20)(17) Other allowance for credit losses(18)(17)
Other accounts receivable, net Other accounts receivable, net199 210  Other accounts receivable, net430 210 
Receivables from affiliates Receivables from affiliates3 16  Receivables from affiliates3 16 
Inventories, net Inventories, net167 170  Inventories, net171 170 
Regulatory assets Regulatory assets316 335  Regulatory assets325 335 
Other Other80 76  Other143 76 
Total current assets Total current assets1,964 1,722  Total current assets2,084 1,722 
Property, plant, and equipment (net of accumulated depreciation and amortization of $6,267 and $6,099 as of March 31, 2022 and December 31, 2021, respectively)26,325 25,995 
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)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 
Deferred debits and other assetsDeferred debits and other assetsDeferred debits and other assets
Regulatory assets Regulatory assets1,883 1,870  Regulatory assets2,134 1,870 
Investments6 6 
Goodwill Goodwill2,625 2,625  Goodwill2,625 2,625 
Receivables from affiliates Receivables from affiliates— 2,761  Receivables from affiliates— 2,761 
Receivable related to Regulatory Agreement Units Receivable related to Regulatory Agreement Units2,484 —  Receivable related to Regulatory Agreement Units1,973 — 
Investments Investments6 6 
Prepaid pension asset Prepaid pension asset1,245 1,086  Prepaid pension asset1,232 1,086 
Other Other481 405  Other467 405 
Total deferred debits and other assets Total deferred debits and other assets8,724 8,753  Total deferred debits and other assets8,437 8,753 
Total assetsTotal assets$37,013 $36,470 Total assets$37,194 $36,470 
See the Combined Notes to Consolidated Financial Statements
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Table of Contents
COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)(In millions)March 31, 2022December 31, 2021(In millions)June 30, 2022December 31, 2021
LIABILITIES AND SHAREHOLDERS’ EQUITYLIABILITIES AND SHAREHOLDERS’ EQUITYLIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilitiesCurrent liabilitiesCurrent liabilities
Accounts payable Accounts payable$553 $647  Accounts payable$756 $647 
Accrued expenses Accrued expenses275 384  Accrued expenses345 384 
�� Payables to affiliates66 121 
Payables to affiliates Payables to affiliates65 121 
Customer deposits Customer deposits98 99  Customer deposits99 99 
Regulatory liabilities Regulatory liabilities190 185  Regulatory liabilities216 185 
Mark-to-market derivative liabilities Mark-to-market derivative liabilities— 18  Mark-to-market derivative liabilities— 18 
Other Other161 133  Other253 133 
Total current liabilities Total current liabilities1,343 1,587  Total current liabilities1,734 1,587 
Long-term debtLong-term debt10,515 9,773 Long-term debt10,516 9,773 
Long-term debt to financing trustLong-term debt to financing trust205 205 Long-term debt to financing trust205 205 
Deferred credits and other liabilitiesDeferred credits and other liabilitiesDeferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits Deferred income taxes and unamortized investment tax credits4,761 4,685  Deferred income taxes and unamortized investment tax credits4,852 4,685 
Regulatory liabilities Regulatory liabilities6,111 6,759 
Asset retirement obligations Asset retirement obligations145 144  Asset retirement obligations145 144 
Non-pension postretirement benefits obligations Non-pension postretirement benefits obligations168 169  Non-pension postretirement benefits obligations168 169 
Regulatory liabilities6,551 6,759 
Mark-to-market derivative liabilities Mark-to-market derivative liabilities144 201  Mark-to-market derivative liabilities103 201 
Other Other615 592  Other544 592 
Total deferred credits and other liabilities Total deferred credits and other liabilities12,384 12,550  Total deferred credits and other liabilities11,923 12,550 
Total liabilities Total liabilities24,447 24,115  Total liabilities24,378 24,115 
Commitments and contingenciesCommitments and contingencies00Commitments and contingencies00
Shareholders’ equityShareholders’ equityShareholders’ equity
Common stock Common stock1,588 1,588  Common stock1,588 1,588 
Other paid-in capital Other paid-in capital9,243 9,076  Other paid-in capital9,411 9,076 
Retained earnings Retained earnings1,735 1,691  Retained earnings1,817 1,691 
Total shareholders’ equity Total shareholders’ equity12,566 12,355  Total shareholders’ equity12,816 12,355 
Total liabilities and shareholders’ equityTotal liabilities and shareholders’ equity$37,013 $36,470 Total liabilities and shareholders’ equity$37,194 $36,470 
See the Combined Notes to Consolidated Financial Statements
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COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY
(Unaudited)
Three Months Ended March 31, 2022Six Months Ended June 30, 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, 2021Balance, December 31, 2021$1,588 $9,076 $1,691 $12,355 Balance, December 31, 2021$1,588 $9,076 $1,691 $12,355 
Net incomeNet income— — 188 188 Net income— — 188 188 
Common stock dividendsCommon stock dividends— — (144)(144)Common stock dividends— — (144)(144)
Contributions from parentContributions from parent— 167 — 167 Contributions from parent— 167 — 167 
Balance, March 31, 2022Balance, March 31, 2022$1,588 $9,243 $1,735 $12,566 Balance, March 31, 2022$1,588 $9,243 $1,735 $12,566 
Net incomeNet income— — 227 227 
Common stock dividendsCommon stock dividends— — (145)(145)
Contributions from parentContributions from parent— 168 — 168 
Balance, June 30, 2022Balance, June 30, 2022$1,588 $9,411 $1,817 $12,816 
Three Months Ended March 31, 2021Six Months Ended June 30, 2021
(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, 2020Balance, December 31, 2020$1,588 $8,285 $1,456 $11,329 Balance, December 31, 2020$1,588 $8,285 $1,456 $11,329 
Net incomeNet income— — 197 197 Net income— — 197 197 
Common stock dividendsCommon stock dividends— — (127)(127)Common stock dividends— — (127)(127)
Contributions from parentContributions from parent— 198 — 198 Contributions from parent— 198 — 198 
Balance, March 31, 2021Balance, March 31, 2021$1,588 $8,483 $1,526 $11,597 Balance, March 31, 2021$1,588 $8,483 $1,526 $11,597 
Net incomeNet income— — 192 192 
Common stock dividendsCommon stock dividends— — (126)(126)
Contributions from parentContributions from parent— 197 — 197 
Balance, June 30, 2021Balance, June 30, 2021$1,588 $8,680 $1,592 $11,860 
See the Combined Notes to Consolidated Financial Statements
1819



Table of Contents

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
 Three Months Ended
March 31,
(In millions)20222021
Operating revenues
Electric operating revenues$734 $649 
Natural gas operating revenues306 228 
Revenues from alternative revenue programs6 10 
Operating revenues from affiliates1 2 
Total operating revenues1,047 889 
Operating expenses
Purchased power229 189 
Purchased fuel145 86 
Purchased power from affiliate33 41 
Operating and maintenance196 193 
Operating and maintenance from affiliates51 41 
Depreciation and amortization92 86 
Taxes other than income taxes47 43 
Total operating expenses793 679 
Operating income254 210 
Other income and (deductions)
Interest expense, net(38)(35)
Interest expense to affiliates(3)(3)
Other, net7 5 
Total other income and (deductions)(34)(33)
Income before income taxes220 177 
Income taxes14 10 
Net income$206 $167 
Comprehensive income$206 $167 
See the Combined Notes to Consolidated Financial Statements
19



Table of Contents
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Cash flows from operating activities
Net income$206 $167 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization92 86 
Deferred income taxes and amortization of investment tax credits14 6 
Other non-cash operating activities15 12 
Changes in assets and liabilities:
Accounts receivable(40)(5)
Receivables from and payables to affiliates, net(31)(2)
Inventories27 13 
Accounts payable and accrued expenses(24)(36)
Income taxes— 3 
Pension and non-pension postretirement benefit contributions(12)(16)
Other assets and liabilities(106)(103)
Net cash flows provided by operating activities141 125 
Cash flows from investing activities
Capital expenditures(344)(295)
Changes in Exelon intercompany money pool— (48)
Other investing activities2 1 
Net cash flows used in investing activities(342)(342)
Cash flows from financing activities
Issuance of long-term debt— 375 
Changes in Exelon intercompany money pool65 (40)
Dividends paid on common stock(100)(85)
Contributions from parent227 — 
Other financing activities(1)(4)
Net cash flows provided by financing activities191 246 
(Decrease) increase in cash, restricted cash, and cash equivalents(10)29 
Cash, restricted cash, and cash equivalents at beginning of period44 26 
Cash, restricted cash, and cash equivalents at end of period$34 $55 
Supplemental cash flow information
(Decrease) increase in capital expenditures not paid$(41)$(44)
 Three Months Ended
June 30,		Six Months Ended
June 30,
(In millions)2022202120222021
Operating revenues
Electric operating revenues$707 $602 $1,441 $1,251 
Natural gas operating revenues108 82 414 310 
Revenues from alternative revenue programs— 7 6 17 
Operating revenues from affiliates1 2 2 4 
Total operating revenues816 693 1,863 1,582 
Operating expenses
Purchased power244 145 472 334 
Purchased fuel39 22 184 108 
Purchased power from affiliate— 40 33 81 
Operating and maintenance168 166 364 360 
Operating and maintenance from affiliates47 43 99 83 
Depreciation and amortization93 87 185 173 
Taxes other than income taxes48 49 95 92 
Total operating expenses639 552 1,432 1,231 
Operating income177 141 431 351 
Other income and (deductions)
Interest expense, net(40)(39)(78)(74)
Interest expense to affiliates(3)(3)(6)(6)
Other, net8 7 16 12 
Total other income and (deductions)(35)(35)(68)(68)
Income before income taxes142 106 363 283 
Income taxes9 2 24 12 
Net income$133 $104 $339 $271 
Comprehensive income$133 $104 $339 $271 
See the Combined Notes to Consolidated Financial Statements
20



Table of Contents
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETSSTATEMENTS OF CASH FLOWS
(Unaudited)
(In millions)March 31, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$26 $36 
Restricted cash and cash equivalents8 8 
Accounts receivable
Customer accounts receivable528489
Customer allowance for credit losses(125)(105)
Customer accounts receivable, net403 384 
Other accounts receivable129116
Other allowance for credit losses(9)(7)
Other accounts receivable, net120 109 
Receivables from affiliates— 1 
Inventories, net
Fossil fuel23 51 
Materials and supplies46 45 
Prepaid utility taxes117 1 
Regulatory assets57 48 
Other30 28 
Total current assets830 711 
Property, plant, and equipment (net of accumulated depreciation and amortization of $4,004 and $3,964 as of March 31, 2022 and December 31, 2021, respectively)11,334 11,117 
Deferred debits and other assets
Regulatory assets1,000 943 
Investments33 34 
Receivables from affiliates— 597 
Receivable related to Regulatory Agreement Units486 — 
Prepaid pension asset401 386 
Other29 36 
Total deferred debits and other assets1,949 1,996 
Total assets$14,113 $13,824 
Six Months Ended
June 30,
(In millions)20222021
Cash flows from operating activities
Net income$339 $271 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization185 173 
Deferred income taxes and amortization of investment tax credits14 21 
Other non-cash operating activities4 (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 expenses5 (46)
Income taxes49 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 activities412 374 
Cash flows from investing activities
Capital expenditures(658)(577)
Other investing activities5 4 
Net cash flows used in investing activities(653)(573)
Cash flows from financing activities
Changes in short-term borrowings210 — 
Issuance of long-term debt350 375 
Retirement of long-term debt(350)— 
Changes in Exelon intercompany money pool— (40)
Dividends paid on common stock(200)(169)
Contributions from parent227 395 
Other financing activities(8)(4)
Net cash flows provided by financing activities229 557 
(Decrease) increase in cash, restricted cash, and cash equivalents(12)358 
Cash, restricted cash, and cash equivalents at beginning of period44 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)
See the Combined Notes to Consolidated Financial Statements
21



Table of Contents
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)June 30, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$23 $36 
Restricted cash and cash equivalents9 8 
Accounts receivable
Customer accounts receivable493489
Customer allowance for credit losses(107)(105)
Customer accounts receivable, net386 384 
Other accounts receivable138116
Other allowance for credit losses(10)(7)
Other accounts receivable, net128 109 
Receivables from affiliates— 1 
Inventories, net
Fossil fuel55 51 
Materials and supplies48 45 
Prepaid utility taxes85 1 
Regulatory assets61 48 
Other36 28 
Total current assets831 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 assets1,033 943 
Receivables from affiliates— 597 
Receivable related to Regulatory Agreement Units292 — 
Investments32 34 
Prepaid pension asset405 386 
Other32 36 
Total deferred debits and other assets1,794 1,996 
Total assets$14,216 $13,824 
See the Combined Notes to Consolidated Financial Statements
22



Table of Contents
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)(In millions)March 31, 2022December 31, 2021(In millions)June 30, 2022December 31, 2021
LIABILITIES AND SHAREHOLDER'S EQUITYLIABILITIES AND SHAREHOLDER'S EQUITYLIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilitiesCurrent liabilitiesCurrent liabilities
Short-term borrowingsShort-term borrowings$210 $— 
Long-term debt due within one yearLong-term debt due within one year$350 $350 Long-term debt due within one year50 350 
Accounts payableAccounts payable477 494 Accounts payable525 494 
Accrued expensesAccrued expenses105 136 Accrued expenses161 136 
Payables to affiliatesPayables to affiliates38 70 Payables to affiliates29 70 
Borrowings from Exelon intercompany money pool65 — 
Customer depositsCustomer deposits50 48 Customer deposits53 48 
Regulatory liabilitiesRegulatory liabilities94 94 Regulatory liabilities75 94 
OtherOther41 35 Other47 35 
Total current liabilitiesTotal current liabilities1,220 1,227 Total current liabilities1,150 1,227 
Long-term debtLong-term debt3,848 3,847 Long-term debt4,142 3,847 
Long-term debt to financing trustsLong-term debt to financing trusts184 184 Long-term debt to financing trusts184 184 
Deferred credits and other liabilitiesDeferred credits and other liabilitiesDeferred credits and other liabilities
Deferred income taxes and unamortized investment tax creditsDeferred income taxes and unamortized investment tax credits2,495 2,421 Deferred income taxes and unamortized investment tax credits2,534 2,421 
Regulatory liabilitiesRegulatory liabilities329 635 
Asset retirement obligationsAsset retirement obligations29 29 Asset retirement obligations29 29 
Non-pension postretirement benefits obligationsNon-pension postretirement benefits obligations287 286 Non-pension postretirement benefits obligations288 286 
Regulatory liabilities523 635 
OtherOther82 83 Other82 83 
Total deferred credits and other liabilitiesTotal deferred credits and other liabilities3,416 3,454 Total deferred credits and other liabilities3,262 3,454 
Total liabilitiesTotal liabilities8,668 8,712 Total liabilities8,738 8,712 
Commitments and contingenciesCommitments and contingencies00Commitments and contingencies00
Shareholder’s equityShareholder’s equityShareholder’s equity
Common stockCommon stock3,655 3,428 Common stock3,655 3,428 
Retained earningsRetained earnings1,790 1,684 Retained earnings1,823 1,684 
Total shareholder’s equityTotal shareholder’s equity5,445 5,112 Total shareholder’s equity5,478 5,112 
Total liabilities and shareholder's equityTotal liabilities and shareholder's equity$14,113 $13,824 Total liabilities and shareholder's equity$14,216 $13,824 
See the Combined Notes to Consolidated Financial Statements
2223



Table of Contents
PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY
(Unaudited)
Three Months Ended March 31, 2022Six Months Ended June 30, 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, 2021Balance, December 31, 2021$3,428 $1,684 $5,112 Balance, December 31, 2021$3,428 $1,684 $5,112 
Net incomeNet income— 206 206 Net income— 206 206 
Common stock dividendsCommon stock dividends— (100)(100)Common stock dividends— (100)(100)
Contributions from parentContributions from parent227 — 227 Contributions from parent227 — 227 
Balance, March 31, 2022Balance, March 31, 2022$3,655 $1,790 $5,445 Balance, March 31, 2022$3,655 $1,790 $5,445 
Net incomeNet income— 133 133 
Common stock dividendsCommon stock dividends— (100)(100)
Balance, June 30, 2022Balance, June 30, 2022$3,655 $1,823 $5,478 
Three Months Ended March 31, 2021Six Months Ended June 30, 2021
(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, 2020Balance, December 31, 2020$3,014 $1,519 $4,533 Balance, December 31, 2020$3,014 $1,519 $4,533 
Net incomeNet income— 167 167 Net income— 167 167 
Common stock dividendsCommon stock dividends— (85)(85)Common stock dividends— (85)(85)
Balance, March 31, 2021Balance, March 31, 2021$3,014 $1,601 $4,615 Balance, March 31, 2021$3,014 $1,601 $4,615 
Net incomeNet income— 104 104 
Common stock dividendsCommon stock dividends— (84)(84)
Contributions from parentContributions from parent395 — 395 
Balance, June 30, 2021Balance, June 30, 2021$3,409 $1,621 $5,030 
See the Combined Notes to Consolidated Financial Statements
2324



Table of Contents

BALTIMORE GAS AND ELECTRIC COMPANY
STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Operating revenues
Electric operating revenues$735 $620 
Natural gas operating revenues424 330 
Revenues from alternative revenue programs(12)18 
Operating revenues from affiliates7 6 
Total operating revenues1,154 974 
Operating expenses
Purchased power285 162 
Purchased fuel151 99 
Purchased power and fuel from affiliate18 70 
Operating and maintenance167 152 
Operating and maintenance from affiliates51 45 
Depreciation and amortization171 152 
Taxes other than income taxes76 72 
Total operating expenses919 752 
Operating income235 222 
Other income and (deductions)
Interest expense, net(35)(34)
Other, net7 8 
Total other income and (deductions)(28)(26)
Income before income taxes207 196 
Income taxes9 (13)
Net income$198 $209 
Comprehensive income$198 $209 
See the Combined Notes to Consolidated Financial Statements
24



Table of Contents
BALTIMORE GAS AND ELECTRIC COMPANY
STATEMENTS OF CASH FLOWS
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Cash flows from operating activities
Net income$198 $209 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization171 152 
Deferred income taxes and amortization of investment tax credits5 (4)
Other non-cash operating activities44 2 
Changes in assets and liabilities:
Accounts receivable(80)12 
Receivables from and payables to affiliates, net(2)(15)
Inventories32 9 
Accounts payable and accrued expenses(30)(59)
Income taxes4 (9)
Pension and non-pension postretirement benefit contributions(56)(65)
Other assets and liabilities(9)(103)
Net cash flows provided by operating activities277 129 
Cash flows from investing activities
Capital expenditures(303)(336)
Other investing activities3 2 
Net cash flows used in investing activities(300)(334)
Cash flows from financing activities
Changes in short-term borrowings120 156 
Dividends paid on common stock(76)(74)
Other financing activities(1)— 
Net cash flows provided by financing activities43 82 
Increase (decrease) in cash, restricted cash, and cash equivalents20 (123)
Cash, restricted cash, and cash equivalents at beginning of period55 145 
Cash, restricted cash, and cash equivalents at end of period$75 $22 
Supplemental cash flow information
Decrease in capital expenditures not paid$(32)$(80)
Three Months Ended
June 30,		Six Months Ended
June 30,
(In millions)2022202120222021
Operating revenues
Electric operating revenues$642 $560 $1,377 $1,180 
Natural gas operating revenues161 125 585 455 
Revenues from alternative revenue programs(20)(10)(32)8 
Operating revenues from affiliates3 7 10 13 
Total operating revenues786 682 1,940 1,656 
Operating expenses
Purchased power241 133 526 295 
Purchased fuel48 27 199 126 
Purchased power and fuel from affiliate— 59 18 129 
Operating and maintenance154 147 321 299 
Operating and maintenance from affiliates51 46 102 91 
Depreciation and amortization152 141 322 293 
Taxes other than income taxes71 67 148 139 
Total operating expenses717 620 1,636 1,372 
Operating income69 62 304 284 
Other income and (deductions)
Interest expense, net(36)(34)(71)(67)
Other, net5 9 11 16 
Total other income and (deductions)(31)(25)(60)(51)
Income before income taxes38 37 244 233 
Income taxes1 (8)10 (21)
Net income$37 $45 $234 $254 
Comprehensive income$37 $45 $234 $254 
See the Combined Notes to Consolidated Financial Statements
25



Table of Contents
BALTIMORE GAS AND ELECTRIC COMPANY
BALANCE SHEETSSTATEMENTS OF CASH FLOWS
(Unaudited)
(In millions)March 31, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$41 $51 
Restricted cash and cash equivalents34 4 
Accounts receivable
Customer accounts receivable519436
Customer allowance for credit losses(59)(38)
    Customer accounts receivable, net460 398 
Other accounts receivable126124
Other allowance for credit losses(11)(9)
     Other accounts receivable, net115 115 
Receivables from affiliates— 1 
Inventories, net
Fossil fuel12 42 
Materials and supplies51 53 
Prepaid utility taxes46 49 
Regulatory assets175 215 
Other11 8 
Total current assets945 936 
Property, plant, and equipment (net of accumulated depreciation and amortization of $4,376 and $4,299 as of March 31, 2022 and December 31, 2021, respectively)10,736 10,577 
Deferred debits and other assets
Regulatory assets467 477 
Investments6 14 
Prepaid pension asset315 276 
Other40 44 
Total deferred debits and other assets828 811 
Total assets$12,509 $12,324 
Six Months Ended
June 30,
(In millions)20222021
Cash flows from operating activities
Net income$234 $254 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization322 293 
Deferred income taxes and amortization of investment tax credits13 11 
Other non-cash operating activities79 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, net190 2 
Income taxes(27)(27)
Regulatory assets and liabilities, net(36)(61)
Pension and non-pension postretirement benefit contributions(59)(71)
Other assets and liabilities24 (35)
Net cash flows provided by operating activities676 388 
Cash flows from investing activities
Capital expenditures(578)(620)
Other investing activities7 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 debt500 600 
Dividends paid on common stock(150)(146)
Contributions from parent186 — 
Other financing activities(7)(6)
Net cash flows provided by financing activities399 448 
Increase in cash, restricted cash, and cash equivalents504 226 
Cash, restricted cash, and cash equivalents at beginning of period55 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)
See the Combined Notes to Consolidated Financial Statements
26



Table of Contents
BALTIMORE GAS AND ELECTRIC COMPANY
BALANCE SHEETS
(Unaudited)
(In millions)June 30, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$354 $51 
Restricted cash and cash equivalents205 4 
Accounts receivable
Customer accounts receivable462436
Customer allowance for credit losses(57)(38)
    Customer accounts receivable, net405 398 
Other accounts receivable122124
Other allowance for credit losses(11)(9)
     Other accounts receivable, net111 115 
Receivables from affiliates— 1 
Inventories, net
Fossil fuel68 42 
Materials and supplies54 53 
Prepaid utility taxes— 49 
Regulatory assets178 215 
Other10 8 
Total current assets1,385 936 
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 assets465 477 
Investments7 14 
Prepaid pension asset307 276 
Other30 44 
Total deferred debits and other assets809 811 
Total assets$13,093 $12,324 
See the Combined Notes to Consolidated Financial Statements
27



Table of Contents
BALTIMORE GAS AND ELECTRIC COMPANY
BALANCE SHEETS
(Unaudited)
(In millions)(In millions)March 31, 2022December 31, 2021(In millions)June 30, 2022December 31, 2021
LIABILITIES AND SHAREHOLDER'S EQUITYLIABILITIES AND SHAREHOLDER'S EQUITYLIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilitiesCurrent liabilitiesCurrent liabilities
Short-term borrowingsShort-term borrowings$250 $130 Short-term borrowings$— $130 
Long-term debt due within one yearLong-term debt due within one year250 250 Long-term debt due within one year250 250 
Accounts payableAccounts payable299 349 Accounts payable339 349 
Accrued expensesAccrued expenses168 176 Accrued expenses133 176 
Payables to affiliatesPayables to affiliates37 48 Payables to affiliates30 48 
Customer depositsCustomer deposits98 97 Customer deposits100 97 
Regulatory liabilitiesRegulatory liabilities35 26 Regulatory liabilities45 26 
OtherOther61 48 Other224 48 
Total current liabilitiesTotal current liabilities1,198 1,124 Total current liabilities1,121 1,124 
Long-term debtLong-term debt3,711 3,711 Long-term debt4,206 3,711 
Deferred credits and other liabilitiesDeferred credits and other liabilitiesDeferred credits and other liabilities
Deferred income taxes and unamortized investment tax creditsDeferred income taxes and unamortized investment tax credits1,755 1,686 Deferred income taxes and unamortized investment tax credits1,777 1,686 
Regulatory liabilitiesRegulatory liabilities869 934 
Asset retirement obligationsAsset retirement obligations26 26 Asset retirement obligations26 26 
Non-pension postretirement benefits obligationsNon-pension postretirement benefits obligations170 175 Non-pension postretirement benefits obligations169 175 
Regulatory liabilities872 934 
OtherOther85 98 Other85 98 
Total deferred credits and other liabilitiesTotal deferred credits and other liabilities2,908 2,919 Total deferred credits and other liabilities2,926 2,919 
Total liabilitiesTotal liabilities7,817 7,754 Total liabilities8,253 7,754 
Commitments and contingenciesCommitments and contingencies00Commitments and contingencies00
Shareholder's equityShareholder's equityShareholder's equity
Common stockCommon stock2,575 2,575 Common stock2,761 2,575 
Retained earningsRetained earnings2,117 1,995 Retained earnings2,079 1,995 
Total shareholder's equityTotal shareholder's equity4,692 4,570 Total shareholder's equity4,840 4,570 
Total liabilities and shareholder's equityTotal liabilities and shareholder's equity$12,509 $12,324 Total liabilities and shareholder's equity$13,093 $12,324 

See the Combined Notes to Consolidated Financial Statements
2728



Table of Contents
BALTIMORE GAS AND ELECTRIC COMPANY
STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY
(Unaudited)
Three Months Ended March 31, 2022
(In millions)Common
Stock		Retained
Earnings		Total
Shareholder's
Equity
Balance, December 31, 2021$2,575 $1,995 $4,570 
Net income— 198 198 
Common stock dividends— (76)(76)
Balance, March 31, 2022$2,575 $2,117 $4,692 
Three Months Ended March 31, 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 
See the Combined Notes to Consolidated Financial Statements
28



Table of Contents


PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Operating revenues
Electric operating revenues$1,323 $1,124 
Natural gas operating revenues83 71 
Revenues from alternative revenue programs(5)46 
Operating revenues from affiliates3 3 
Total operating revenues1,404 1,244 
Operating expenses
Purchased power487 348 
Purchased fuel42 33 
Purchased power from affiliates50 98 
Operating and maintenance248 216 
Operating and maintenance from affiliates51 40 
Depreciation and amortization218 210 
Taxes other than income taxes119 113 
Total operating expenses1,215 1,058 
Operating income189 186 
Other income and (deductions)
Interest expense, net(69)(67)
Other, net17 17 
Total other income and (deductions)(52)(50)
Income before income taxes137 136 
Income taxes7 8 
Net income$130 $128 
Comprehensive income$130 $128 
Six Months Ended June 30, 2022
(In millions)Common
Stock		Retained
Earnings		Total
Shareholder's
Equity
Balance, December 31, 2021$2,575 $1,995 $4,570 
Net income— 198 198 
Common stock dividends— (76)(76)
Balance, March 31, 2022$2,575 $2,117 $4,692 
Net income— 37 37 
Common stock dividends— (75)(75)
Contributions from parent186 — 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
29



Table of Contents

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CASH FLOWSOPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Cash flows from operating activities
Net income$130 $128 
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization218 210 
Deferred income taxes and amortization of investment tax credits2 4 
Other non-cash operating activities35 (25)
Changes in assets and liabilities:
Accounts receivable(21)56 
Receivables from and payables to affiliates, net(51)(18)
Inventories7 5 
Accounts payable and accrued expenses(23)(24)
Income taxes5 3 
Pension and non-pension postretirement benefit contributions(67)(36)
Other assets and liabilities(3)(94)
Net cash flows provided by operating activities232 209 
Cash flows from investing activities
Capital expenditures(409)(456)
Other investing activities2 1 
Net cash flows used in investing activities(407)(455)
Cash flows from financing activities
Changes in short-term borrowings(468)(368)
Issuance of long-term debt700 625 
Retirement of long-term debt— (44)
Changes in Exelon intercompany money pool39 3 
Distributions to member(102)(81)
Contributions from member704 560 
Other financing activities(9)(5)
Net cash flows provided by financing activities864 690 
Increase in cash, restricted cash, and cash equivalents689 444 
Cash, restricted cash, and cash equivalents at beginning of period213 160 
Cash, restricted cash, and cash equivalents at end of period$902 $604 
Supplemental cash flow information
Decrease in capital expenditures not paid$(55)$(33)
Three Months Ended
June 30,		Six Months Ended
June 30,
(In millions)2022202120222021
Operating revenues
Electric operating revenues$1,199 $1,071 $2,522 $2,195 
Natural gas operating revenues37 24 120 94 
Revenues from alternative revenue programs(17)41 (22)88 
Operating revenues from affiliates2 4 6 7 
Total operating revenues1,221 1,140 2,626 2,384 
Operating expenses
Purchased power401 308 888 656 
Purchased fuel19 9 61 41 
Purchased power from affiliates— 79 50 177 
Operating and maintenance245 217 493 434 
Operating and maintenance from affiliates47 39 98 79 
Depreciation and amortization240 194 459 404 
Taxes other than income taxes114 109 233 222 
Total operating expenses1,066 955 2,282 2,013 
Operating income155 185 344 371 
Other income and (deductions)
Interest expense, net(73)(67)(143)(134)
Other, net19 20 37 36 
Total other income and (deductions)(54)(47)(106)(98)
Income before income taxes101 138 238 273 
Income taxes1 (3)8 5 
Equity in earnings of unconsolidated affiliate— — — 1 
Net income$100 $141 $230 $269 
Comprehensive income$100 $141 $230 $269 
See the Combined Notes to Consolidated Financial Statements
30



Table of Contents
PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETSSTATEMENTS OF CASH FLOWS
(Unaudited)
(In millions)March 31, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$796 $136 
Restricted cash and cash equivalents106 77 
Accounts receivable
Customer accounts receivable618616
Customer allowance for credit losses(113)(104)
Customer accounts receivable, net505 512 
Other accounts receivable288283
Other allowance for credit losses(41)(39)
Other accounts receivable, net247 244 
Receivables from affiliates— 2 
Inventories, net
Fossil fuel4 11 
Materials and supplies209 209 
Regulatory assets432 432 
Other69 69 
Total current assets2,368 1,692 
Property, plant, and equipment (net of accumulated depreciation and amortization of $2,256 and $2,108 as of March 31, 2022 and December 31, 2021, respectively)16,701 16,498 
Deferred debits and other assets
Regulatory assets1,770 1,794 
Investments142 145 
Goodwill4,005 4,005 
Prepaid pension asset392 344 
Deferred income taxes5 8 
Other253 258 
Total deferred debits and other assets6,567 6,554 
Total assets$25,636 $24,744 
Six Months Ended
June 30,
(In millions)20222021
Cash flows from operating activities
Net income$230 $269 
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization459 404 
Deferred income taxes and amortization of investment tax credits(7)10 
Other non-cash operating activities76 (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 expenses10 (35)
Collateral received, net403 — 
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 activities790 377 
Cash flows from investing activities
Capital expenditures(776)(889)
Other investing activities3 (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 debt700 625 
Retirement of long-term debt(200)(249)
Changes in Exelon intercompany money pool17 (12)
Distributions to member(395)(414)
Contributions from member704 560 
Other financing activities(12)(8)
Net cash flows provided by financing activities389 466 
Increase (decrease) in cash, restricted cash, and cash equivalents406 (48)
Cash, restricted cash, and cash equivalents at beginning of period213 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)
See the Combined Notes to Consolidated Financial Statements
31



Table of Contents
PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)June 30, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$278 $136 
Restricted cash and cash equivalents341 77 
Accounts receivable
Customer accounts receivable676616
Customer allowance for credit losses(109)(104)
Customer accounts receivable, net567 512 
Other accounts receivable291283
Other allowance for credit losses(42)(39)
Other accounts receivable, net249 244 
Receivables from affiliates1 2 
Inventories, net
Fossil fuel10 11 
Materials and supplies217 209 
Regulatory assets435 432 
Other90 69 
Total current assets2,188 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 assets1,714 1,794 
Goodwill4,005 4,005 
Investments139 145 
Prepaid pension asset380 344 
Deferred income taxes6 8 
Other245 258 
Total deferred debits and other assets6,489 6,554 
Total assets$25,592 $24,744 
See the Combined Notes to Consolidated Financial Statements
32



Table of Contents
PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)(In millions)March 31, 2022December 31, 2021(In millions)June 30, 2022December 31, 2021
LIABILITIES AND MEMBER'S EQUITYLIABILITIES AND MEMBER'S EQUITYLIABILITIES AND MEMBER'S EQUITY
Current liabilitiesCurrent liabilitiesCurrent liabilities
Short-term borrowingsShort-term borrowings$— $468 Short-term borrowings$43 $468 
Long-term debt due within one yearLong-term debt due within one year400 399 Long-term debt due within one year200 399 
Accounts payableAccounts payable522 578 Accounts payable574 578 
Accrued expensesAccrued expenses264 281 Accrued expenses246 281 
Payables to affiliatesPayables to affiliates51 104 Payables to affiliates50 104 
Borrowings from Exelon intercompany money poolBorrowings from Exelon intercompany money pool46 7 Borrowings from Exelon intercompany money pool24 7 
Customer depositsCustomer deposits80 81 Customer deposits81 81 
Regulatory liabilitiesRegulatory liabilities72 68 Regulatory liabilities71 68 
Unamortized energy contract liabilitiesUnamortized energy contract liabilities13 89 Unamortized energy contract liabilities11 89 
PPA termination obligationPPA termination obligation85 — PPA termination obligation87 — 
OtherOther215 171 Other580 171 
Total current liabilitiesTotal current liabilities1,748 2,246 Total current liabilities1,967 2,246 
Long-term debtLong-term debt7,833 7,148 Long-term debt7,827 7,148 
Deferred credits and other liabilitiesDeferred credits and other liabilitiesDeferred credits and other liabilities
Deferred income taxes and unamortized investment tax creditsDeferred income taxes and unamortized investment tax credits2,723 2,675 Deferred income taxes and unamortized investment tax credits2,752 2,675 
Regulatory liabilitiesRegulatory liabilities1,142 1,238 
Asset retirement obligationsAsset retirement obligations70 70 Asset retirement obligations70 70 
Non-pension postretirement benefit obligationsNon-pension postretirement benefit obligations60 66 Non-pension postretirement benefit obligations57 66 
Regulatory liabilities1,182 1,238 
Unamortized energy contract liabilitiesUnamortized energy contract liabilities42 146 Unamortized energy contract liabilities38 146 
OtherOther661 570 Other615 570 
Total deferred credits and other liabilitiesTotal deferred credits and other liabilities4,738 4,765 Total deferred credits and other liabilities4,674 4,765 
Total liabilitiesTotal liabilities14,319 14,159 Total liabilities14,468 14,159 
Commitments and contingenciesCommitments and contingencies00Commitments and contingencies00
Member's equityMember's equityMember's equity
Membership interestMembership interest11,499 10,795 Membership interest11,499 10,795 
Undistributed lossesUndistributed losses(182)(210)Undistributed losses(375)(210)
Total member's equityTotal member's equity11,317 10,585 Total member's equity11,124 10,585 
Total liabilities and member's equityTotal liabilities and member's equity$25,636 $24,744 Total liabilities and member's equity$25,592 $24,744 
See the Combined Notes to Consolidated Financial Statements
3233



Table of Contents
PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES
CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY
(Unaudited)
Three Months Ended March 31, 2022Six Months Ended June 30, 2022
(In millions)(In millions)Membership InterestUndistributed (Losses)/EarningsTotal Member's Equity(In millions)Membership InterestUndistributed (Losses)/EarningsTotal Member's Equity
Balance, December 31, 2021Balance, December 31, 2021$10,795 $(210)$10,585 Balance, December 31, 2021$10,795 $(210)$10,585 
Net incomeNet income— 130 130 Net income— 130 130 
Distributions to memberDistributions to member— (102)(102)Distributions to member— (102)(102)
Contributions from memberContributions from member704 — 704 Contributions from member704 — 704 
Balance, March 31, 2022Balance, March 31, 2022$11,499 $(182)$11,317 Balance, March 31, 2022$11,499 $(182)$11,317 
Net incomeNet income— 100 100 
Distributions to memberDistributions to member— (293)(293)
Balance, June 30, 2022Balance, June 30, 2022$11,499 $(375)$11,124 

Three Months Ended March 31, 2021Six Months Ended June 30, 2021
(In millions)(In millions)Membership InterestUndistributed (Losses)/EarningsTotal Member's Equity(In millions)Membership InterestUndistributed (Losses)/EarningsTotal Member's Equity
Balance, December 31, 2020Balance, December 31, 2020$10,112 $(68)$10,044 Balance, December 31, 2020$10,112 $(68)$10,044 
Net incomeNet income— 128 128 Net income— 128 128 
Distributions to memberDistributions to member— (81)(81)Distributions to member— (81)(81)
Contributions from memberContributions from member560 — 560 Contributions from member560 — 560 
Balance, March 31, 2021Balance, March 31, 2021$10,672 $(21)$10,651 Balance, March 31, 2021$10,672 $(21)$10,651 
Net incomeNet income— 141 141 
Distributions to memberDistributions to member— (333)(333)
Balance, June 30, 2021Balance, June 30, 2021$10,672 $(213)$10,459 
See the Combined Notes to Consolidated Financial Statements
3334



Table of Contents

POTOMAC ELECTRIC POWER COMPANY
STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Operating revenues
Electric operating revenues620 $526 
Revenues from alternative revenue programs(7)26 
Operating revenues from affiliates1 1 
Total operating revenues614 553 
Operating expenses
Purchased power174 92 
Purchased power from affiliate39 74 
Operating and maintenance73 56 
Operating and maintenance from affiliates58 52 
Depreciation and amortization108 102 
Taxes other than income taxes95 90 
Total operating expenses547 466 
Operating income67 87 
Other income and (deductions)
Interest expense, net(36)(34)
Other, net13 12 
Total other income and (deductions)(23)(22)
Income before income taxes44 65 
Income taxes(2)6 
Net income$46 $59 
Comprehensive income$46 $59 
See the Combined Notes to Consolidated Financial Statements
34



Table of Contents
POTOMAC ELECTRIC POWER COMPANY
STATEMENTS OF CASH FLOWS
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Cash flows from operating activities
Net income$46 $59 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization108 102 
Deferred income taxes and amortization of investment tax credits(2)4 
Other non-cash operating activities12 (25)
Changes in assets and liabilities:
Accounts receivable(2)26 
Receivables from and payables to affiliates, net(25)(9)
Inventories— 1 
Accounts payable and accrued expenses5 — 
Income taxes1 2 
Pension and non-pension postretirement benefit contributions(5)(5)
Other assets and liabilities(18)(58)
Net cash flows provided by operating activities120 97 
Cash flows from investing activities
Capital expenditures(218)(220)
Other investing activities1 1 
Net cash flows used in investing activities(217)(219)
Cash flows from financing activities
Changes in short-term borrowings(175)(35)
Issuance of long-term debt400 150 
Dividends paid on common stock(42)(28)
Contributions from parent387 138 
Other financing activities(5)(1)
Net cash flows provided by financing activities565 224 
Increase in cash, restricted cash, and cash equivalents468 102 
Cash, restricted cash, and cash equivalents at beginning of period68 65 
Cash, restricted cash, and cash equivalents at end of period$536 $167 
Supplemental cash flow information
Decrease in capital expenditures not paid$(36)$(16)
Three Months Ended
June 30,		Six Months Ended
June 30,
(In millions)2022202120222021
Operating revenues
Electric operating revenues$580 $503 $1,200 $1,027 
Revenues from alternative revenue programs(1)19 (7)46 
Operating revenues from affiliates2 1 2 3 
Total operating revenues581 523 1,195 1,076 
Operating expenses
Purchased power162 76 336 168 
Purchased power from affiliate— 57 39 130 
Operating and maintenance72 62 145 118 
Operating and maintenance from affiliates56 51 115 103 
Depreciation and amortization105 96 213 199 
Taxes other than income taxes92 87 186 177 
Total operating expenses487 429 1,034 895 
Operating income94 94 161 181 
Other income and (deductions)
Interest expense, net(38)(35)(74)(69)
Other, net13 13 26 25 
Total other income and (deductions)(25)(22)(48)(44)
Income before income taxes69 72 113 137 
Income taxes(1)(3)(3)3 
Net income$70 $75 $116 $134 
Comprehensive income$70 $75 $116 $134 
See the Combined Notes to Consolidated Financial Statements
35



Table of Contents
POTOMAC ELECTRIC POWER COMPANY
BALANCE SHEETSSTATEMENTS OF CASH FLOWS
(Unaudited)
(In millions)March 31, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$502 $34 
Restricted cash and cash equivalents34 34 
Accounts receivable
Customer accounts receivable278277
Customer allowance for credit losses(40)(37)
Customer accounts receivable, net238 240 
Other accounts receivable157160
Other allowance for credit losses(18)(16)
Other accounts receivable, net139 144 
Inventories, net119 119 
Regulatory assets216 213 
Other29 25 
Total current assets1,277 809 
Property, plant, and equipment (net of accumulated depreciation and amortization of $3,929 and $3,875 as of March 31, 2022 and December 31, 2021, respectively)8,229 8,104 
Deferred debits and other assets
Regulatory assets496 532 
Investments119 120 
Prepaid pension asset279 279 
Other58 59 
Total deferred debits and other assets952 990 
Total assets$10,458 $9,903 
Six Months Ended
June 30,
(In millions)20222021
Cash flows from operating activities
Net income$116 $134 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization213 199 
Deferred income taxes and amortization of investment tax credits(7)10 
Other non-cash operating activities17 (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 expenses6 (26)
Collateral received, net85 — 
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 activities241 135 
Cash flows from investing activities
Capital expenditures(402)(439)
Other investing activities2 (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 debt400 150 
Retirement of long-term debt(200)— 
Changes in PHI intercompany money pool73 9 
Dividends paid on common stock(300)(123)
Contributions from parent387 138 
Other financing activities(6)(2)
Net cash flows provided by financing activities222 291 
Increase (decrease) in cash, restricted cash, and cash equivalents63 (15)
Cash, restricted cash, and cash equivalents at beginning of period68 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)
See the Combined Notes to Consolidated Financial Statements
36



Table of Contents
POTOMAC ELECTRIC POWER COMPANY
BALANCE SHEETS
(Unaudited)
(In millions)June 30, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$14 $34 
Restricted cash and cash equivalents117 34 
Accounts receivable
Customer accounts receivable328277
Customer allowance for credit losses(42)(37)
Customer accounts receivable, net286 240 
Other accounts receivable165160
Other allowance for credit losses(20)(16)
Other accounts receivable, net145 144 
Receivables from affiliates9 — 
Inventories, net125 119 
Regulatory assets220 213 
Other12 25 
Total current assets928 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 assets478 532 
Investments118 120 
Prepaid pension asset277 279 
Other60 59 
Total deferred debits and other assets933 990 
Total assets$10,226 $9,903 
See the Combined Notes to Consolidated Financial Statements
37



Table of Contents
POTOMAC ELECTRIC POWER COMPANY
BALANCE SHEETS
(Unaudited)
(In millions)(In millions)March 31, 2022December 31, 2021(In millions)June 30, 2022December 31, 2021
LIABILITIES AND SHAREHOLDER'S EQUITYLIABILITIES AND SHAREHOLDER'S EQUITYLIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilitiesCurrent liabilitiesCurrent liabilities
Short-term borrowingsShort-term borrowings$— $175 Short-term borrowings$43 $175 
Long-term debt due within one yearLong-term debt due within one year314 313 Long-term debt due within one year114 313 
Accounts payableAccounts payable246 272 Accounts payable269 272 
Accrued expensesAccrued expenses158 160 Accrued expenses124 160 
Payables to affiliatesPayables to affiliates34 59 Payables to affiliates29 59 
Borrowings from PHI intercompany money poolBorrowings from PHI intercompany money pool73 — 
Customer depositsCustomer deposits36 35 Customer deposits36 35 
Regulatory liabilitiesRegulatory liabilities18 14 Regulatory liabilities12 14 
Merger related obligationMerger related obligation27 27 Merger related obligation25 27 
OtherOther64 55 Other149 55 
Total current liabilitiesTotal current liabilities897 1,110 Total current liabilities874 1,110 
Long-term debtLong-term debt3,527 3,132 Long-term debt3,528 3,132 
Deferred credits and other liabilitiesDeferred credits and other liabilitiesDeferred credits and other liabilities
Deferred income taxes and unamortized investment tax creditsDeferred income taxes and unamortized investment tax credits1,293 1,275 Deferred income taxes and unamortized investment tax credits1,314 1,275 
Regulatory liabilitiesRegulatory liabilities507 549 
Asset retirement obligationsAsset retirement obligations45 45 Asset retirement obligations45 45 
Non-pension postretirement benefit obligationsNon-pension postretirement benefit obligations— 3 Non-pension postretirement benefit obligations— 3 
Regulatory liabilities533 549 
OtherOther297 314 Other280 314 
Total deferred credits and other liabilitiesTotal deferred credits and other liabilities2,168 2,186 Total deferred credits and other liabilities2,146 2,186 
Total liabilitiesTotal liabilities6,592 6,428 Total liabilities6,548 6,428 
Commitments and contingenciesCommitments and contingencies00Commitments and contingencies00
Shareholder's equityShareholder's equityShareholder's equity
Shareholder's Equity
Common stockCommon stock2,689 2,302 Common stock2,689 2,302 
Retained earningsRetained earnings1,177 1,173 Retained earnings989 1,173 
Total shareholder's equityTotal shareholder's equity3,866 3,475 Total shareholder's equity3,678 3,475 
Total liabilities and shareholder's equityTotal liabilities and shareholder's equity$10,458 $9,903 Total liabilities and shareholder's equity$10,226 $9,903 
See the Combined Notes to Consolidated Financial Statements
3738



Table of Contents
POTOMAC ELECTRIC POWER COMPANY
STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY
(Unaudited)
Three Months Ended March 31, 2022Six Months Ended June 30, 2022
(In millions)(In millions)Common StockRetained EarningsTotal Shareholder's Equity(In millions)Common StockRetained EarningsTotal Shareholder's Equity
Balance, December 31, 2021Balance, December 31, 2021$2,302 $1,173 $3,475 Balance, December 31, 2021$2,302 $1,173 $3,475 
Net incomeNet income— 46 46 Net income— 46 46 
Common stock dividendsCommon stock dividends— (42)(42)Common stock dividends— (42)(42)
Contributions from parentContributions from parent387 — 387 Contributions from parent387 — 387 
Balance, March 31, 2022Balance, March 31, 2022$2,689 $1,177 $3,866 Balance, March 31, 2022$2,689 $1,177 $3,866 
Net incomeNet income— 70 70 
Common stock dividendsCommon stock dividends— (258)(258)
Balance, June 30, 2022Balance, June 30, 2022$2,689 $989 $3,678 

Three Months Ended March 31, 2021Six Months Ended June 30, 2021
(In millions)(In millions)Common StockRetained EarningsTotal Shareholder's Equity(In millions)Common StockRetained EarningsTotal Shareholder's Equity
Balance, December 31, 2020Balance, December 31, 2020$2,058 $1,145 $3,203 Balance, December 31, 2020$2,058 $1,145 $3,203 
Net incomeNet income— 59 59 Net income— 59 59 
Common stock dividendsCommon stock dividends— (28)(28)Common stock dividends— (28)(28)
Contributions from parentContributions from parent138 — 138 Contributions from parent138 — 138 
Balance, March 31, 2021Balance, March 31, 2021$2,196 $1,176 $3,372 Balance, March 31, 2021$2,196 $1,176 $3,372��
Net incomeNet income— 75 75 
Common stock dividendsCommon stock dividends— (95)(95)
Balance, June 30, 2021Balance, June 30, 2021$2,196 $1,156 $3,352 

See the Combined Notes to Consolidated Financial Statements
3839



Table of Contents

DELMARVA POWER & LIGHT COMPANY
STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Operating revenues
Electric operating revenues$348 $300 
Natural gas operating revenues83 71 
Revenues from alternative revenue programs(1)9 
Operating revenues from affiliates1 2 
Total operating revenues431 382 
Operating expenses
Purchased power137 103 
Purchased fuel42 33 
Purchased power from affiliates10 20 
Operating and maintenance51 44 
Operating and maintenance from affiliates42 39 
Depreciation and amortization57 53 
Taxes other than income taxes18 17 
Total operating expenses357 309 
Operating income74 73 
Other income and (deductions)
Interest expense, net(16)(15)
Other, net2 3 
Total other income and (deductions)(14)(12)
Income before income taxes60 61 
Income taxes4 5 
Net income$56 $56 
Comprehensive income$56 $56 
See the Combined Notes to Consolidated Financial Statements
39



Table of Contents
DELMARVA POWER & LIGHT COMPANY
STATEMENTS OF CASH FLOWS
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Cash flows from operating activities
Net income$56 $56 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization57 53 
Deferred income taxes and amortization of investment tax credits5 2 
Other non-cash operating activities9 (1)
Changes in assets and liabilities:
Accounts receivable(17)15 
Receivables from and payables to affiliates, net(17)(11)
Inventories8 2 
Accounts payable and accrued expenses15 11 
Income taxes(1)3 
Pension and non-pension postretirement benefit contributions(1)— 
Other assets and liabilities33 (26)
Net cash flows provided by operating activities147 104 
Cash flows from investing activities
Capital expenditures(103)(112)
Other investing activities1 — 
Net cash flows used in investing activities(102)(112)
Cash flows from financing activities
Changes in short-term borrowings(149)(146)
Issuance of long-term debt125 125 
Dividends paid on common stock(41)(40)
Contributions from parent144 120 
Other financing activities(2)(2)
Net cash flows provided by financing activities77 57 
Increase in cash, restricted cash, and cash equivalents122 49 
Cash, restricted cash, and cash equivalents at beginning of period71 15 
Cash, restricted cash, and cash equivalents at end of period$193 $64 
Supplemental cash flow information
Decrease in capital expenditures not paid$(8)$(15)
Three Months Ended
June 30,		Six Months Ended
June 30,
(In millions)2022202120222021
Operating revenues
Electric operating revenues$295 $262 $643 $562 
Natural gas operating revenues37 24 120 95 
Revenues from alternative revenue programs(2)10 (3)19 
Operating revenues from affiliates2 2 3 4 
Total operating revenues332 298 763 680 
Operating expenses
Purchased power116 82 253 185 
Purchased fuel19 9 61 41 
Purchased power from affiliates— 17 10 37 
Operating and maintenance45 41 97 85 
Operating and maintenance from affiliates43 39 84 79 
Depreciation and amortization56 51 113 104 
Taxes other than income taxes17 16 35 33 
Total operating expenses296 255 653 564 
Operating income36 43 110 116 
Other income and (deductions)
Interest expense, net(17)(16)(33)(30)
Other, net4 4 6 6 
Total other income and (deductions)(13)(12)(27)(24)
Income before income taxes23 31 83 92 
Income taxes2 1 6 6 
Net income$21 $30 $77 $86 
Comprehensive income$21 $30 $77 $86 
See the Combined Notes to Consolidated Financial Statements
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DELMARVA POWER & LIGHT COMPANY
BALANCE SHEETSSTATEMENTS OF CASH FLOWS
(Unaudited)
(In millions)March 31, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$120 $28 
Restricted cash and cash equivalents73 43 
Accounts receivable
Customer accounts receivable164149
Customer allowance for credit losses(24)(18)
Customer accounts receivable, net140 131 
Other accounts receivable6258
Other allowance for credit losses(9)(8)
Other accounts receivable, net53 50 
Receivables from affiliates— 1 
Inventories, net
Fossil fuel4 11 
Materials and supplies53 54 
Prepaid utility taxes10 20 
Regulatory assets66 68 
Other19 16 
Total current assets538 422 
Property, plant, and equipment (net of accumulated depreciation and amortization of $1,671 and $1,635 as of March 31, 2022 and December 31, 2021, respectively)4,612 4,560 
Deferred debits and other assets
Regulatory assets208 212 
Prepaid pension asset157 157 
Other58 61 
Total deferred debits and other assets423 430 
Total assets$5,573 $5,412 
Six Months Ended
June 30,
(In millions)20222021
Cash flows from operating activities
Net income$77 $86 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization113 104 
Deferred income taxes and amortization of investment tax credits3 4 
Other non-cash operating activities13 (12)
Changes in assets and liabilities:
Accounts receivable(8)24 
Receivables from and payables to affiliates, net(3)(12)
Inventories1 — 
Accounts payable and accrued expenses12 7 
Collateral received, net180 — 
Income taxes6 14 
Regulatory assets and liabilities, net(11)(13)
Pension and non-pension postretirement benefit contributions(1)— 
Other assets and liabilities1 (9)
Net cash flows provided by operating activities383 193 
Cash flows from investing activities
Capital expenditures(194)(211)
Changes in PHI intercompany money pool(73)(9)
Other investing activities2 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 debt125 125 
Dividends paid on common stock(56)(63)
Contributions from parent144 120 
Other financing activities(4)(3)
Net cash flows provided by financing activities60 33 
Increase in cash, restricted cash, and cash equivalents178 7 
Cash, restricted cash, and cash equivalents at beginning of period71 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)
See the Combined Notes to Consolidated Financial Statements
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DELMARVA POWER & LIGHT COMPANY
BALANCE SHEETS
(Unaudited)
(In millions)June 30, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$26 $28 
Restricted cash and cash equivalents223 43 
Accounts receivable
Customer accounts receivable154149
Customer allowance for credit losses(22)(18)
Customer accounts receivable, net132 131 
Other accounts receivable5558
Other allowance for credit losses(8)(8)
Other accounts receivable, net47 50 
Receivables from affiliates— 1 
Receivable from PHI intercompany pool73 — 
Inventories, net
Fossil fuel10 11 
Materials and supplies54 54 
Prepaid utility taxes— 20 
Regulatory assets68 68 
Other29 16 
Total current assets662 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 assets204 212 
Prepaid pension asset156 157 
Other59 61 
Total deferred debits and other assets419 430 
Total assets$5,742 $5,412 
See the Combined Notes to Consolidated Financial Statements
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DELMARVA POWER & LIGHT COMPANY
BALANCE SHEETS
(Unaudited)
(In millions)(In millions)March 31, 2022December 31, 2021(In millions)June 30, 2022December 31, 2021
LIABILITIES AND SHAREHOLDER'S EQUITYLIABILITIES AND SHAREHOLDER'S EQUITYLIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilitiesCurrent liabilitiesCurrent liabilities
Short-term borrowingsShort-term borrowings$— $149 Short-term borrowings$— $149 
Long-term debt due within one yearLong-term debt due within one year83 83 Long-term debt due within one year84 83 
Accounts payableAccounts payable128 131 Accounts payable141 131 
Accrued expensesAccrued expenses50 40 Accrued expenses40 40 
Payables to affiliatesPayables to affiliates15 33 Payables to affiliates29 33 
Customer depositsCustomer deposits27 28 Customer deposits27 28 
Regulatory liabilitiesRegulatory liabilities33 25 Regulatory liabilities31 25 
OtherOther88 59 Other239 59 
Total current liabilitiesTotal current liabilities424 548 Total current liabilities591 548 
Long-term debtLong-term debt1,852 1,727 Long-term debt1,854 1,727 
Deferred credits and other liabilitiesDeferred credits and other liabilitiesDeferred credits and other liabilities
Deferred income taxes and unamortized investment tax creditsDeferred income taxes and unamortized investment tax credits825 803 Deferred income taxes and unamortized investment tax credits830 803 
Regulatory liabilitiesRegulatory liabilities415 441 
Asset retirement obligationsAsset retirement obligations16 16 Asset retirement obligations16 16 
Non-pension postretirement benefits obligationsNon-pension postretirement benefits obligations10 11 Non-pension postretirement benefits obligations10 11 
Regulatory liabilities423 441 
OtherOther87 89 Other84 89 
Total deferred credits and other liabilitiesTotal deferred credits and other liabilities1,361 1,360 Total deferred credits and other liabilities1,355 1,360 
Total liabilitiesTotal liabilities3,637 3,635 Total liabilities3,800 3,635 
Commitments and contingenciesCommitments and contingencies00Commitments and contingencies00
Shareholder's equityShareholder's equityShareholder's equity
Common stockCommon stock1,353 1,209 Common stock1,353 1,209 
Retained earningsRetained earnings583 568 Retained earnings589 568 
Total shareholder's equityTotal shareholder's equity1,936 1,777 Total shareholder's equity1,942 1,777 
Total liabilities and shareholder's equityTotal liabilities and shareholder's equity$5,573 $5,412 Total liabilities and shareholder's equity$5,742 $5,412 
See the Combined Notes to Consolidated Financial Statements
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DELMARVA POWER & LIGHT COMPANY
STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY
(Unaudited)
Three Months Ended March 31, 2022Six Months Ended June 30, 2022
(In millions)(In millions)Common StockRetained EarningsTotal Shareholder's Equity(In millions)Common StockRetained EarningsTotal Shareholder's Equity
Balance, December 31, 2021Balance, December 31, 2021$1,209 $568 $1,777 Balance, December 31, 2021$1,209 $568 $1,777 
Net incomeNet income— 56 56 Net income— 56 56 
Common stock dividendsCommon stock dividends— (41)(41)Common stock dividends— (41)(41)
Contributions from parentContributions from parent144 — 144 Contributions from parent144 — 144 
Balance, March 31, 2022Balance, March 31, 2022$1,353 $583 $1,936 Balance, March 31, 2022$1,353 $583 $1,936 
Net incomeNet income— 21 21 
Common stock dividendsCommon stock dividends— (15)(15)
Balance, June 30, 2022Balance, June 30, 2022$1,353 $589 $1,942 

Three Months Ended March 31, 2021Six Months Ended June 30, 2021
(In millions)(In millions)Common StockRetained EarningsTotal Shareholder's Equity(In millions)Common StockRetained EarningsTotal Shareholder's Equity
Balance, December 31, 2020Balance, December 31, 2020$1,089 $587 $1,676 Balance, December 31, 2020$1,089 $587 $1,676 
Net incomeNet income— 56 56 Net income— 56 56 
Common stock dividendsCommon stock dividends— (40)(40)Common stock dividends— (40)(40)
Contributions from parentContributions from parent120 — 120 Contributions from parent120 — 120 
Balance, March 31, 2021Balance, March 31, 2021$1,209 $603 $1,812 Balance, March 31, 2021$1,209 $603 $1,812 
Net incomeNet income— 30 30 
Common stock dividendsCommon stock dividends— (23)(23)
Balance, June 30, 2021Balance, June 30, 2021$1,209 $610 $1,819 

See the Combined Notes to Consolidated Financial Statements
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ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Operating revenues
Electric operating revenues$345 $298 
Revenues from alternative revenue programs3 11 
Operating revenues from affiliates1 1 
Total operating revenues349 310 
Operating expenses
Purchased power176 153 
Purchased power from affiliate2 4 
Operating and maintenance47 42 
Operating and maintenance from affiliates37 34 
Depreciation and amortization47 47 
Taxes other than income taxes2 2 
Total operating expenses311 282 
Operating income38 28 
Other income and (deductions)
Interest expense, net(14)(15)
Other, net3 1 
Total other income and (deductions)(11)(14)
Income before income taxes27 14 
Income taxes1 — 
Net income$26 $14 
Comprehensive income$26 $14 
See the Combined Notes to Consolidated Financial Statements
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ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)
Three Months Ended
March 31,
(In millions)20222021
Cash flows from operating activities
Net income$26 $14 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization47 47 
Deferred income taxes and amortization of investment tax credits1 (1)
Other non-cash operating activities2 (7)
Changes in assets and liabilities:
Accounts receivable(1)13 
Receivables from and payables to affiliates, net(6)1 
Inventories(1)3 
Accounts payable and accrued expenses(17)(11)
Income taxes— 1 
Pension and non-pension postretirement benefit contributions(7)(3)
Other assets and liabilities— (3)
Net cash flows provided by operating activities44 54 
Cash flows from investing activities
Capital expenditures(87)(123)
Net cash flows used in investing activities(87)(123)
Cash flows from financing activities
Changes in short-term borrowings(144)(187)
Issuance of long-term debt175 350 
Retirement of long-term debt— (44)
Dividends paid on common stock(19)(14)
Contributions from parent173 303 
Other financing activities(3)(3)
Net cash flows provided by financing activities182 405 
Increase in cash, restricted cash, and cash equivalents139 336 
Cash, restricted cash, and cash equivalents at beginning of period29 30 
Cash, restricted cash, and cash equivalents at end of period$168 $366 
Supplemental cash flow information
Decrease in capital expenditures not paid$(10)$(2)
Three Months Ended
June 30,		Six Months Ended
June 30,
(In millions)2022202120222021
Operating revenues
Electric operating revenues$323 $306 $668 $605 
Revenues from alternative revenue programs(15)12 (12)23 
Operating revenues from affiliates1 1 2 1 
Total operating revenues309 319 658 629 
Operating expenses
Purchased power123 149 299 302 
Purchased power from affiliate— 5 2 9 
Operating and maintenance50 39 97 82 
Operating and maintenance from affiliates36 34 73 68 
Depreciation and amortization72 40 118 87 
Taxes other than income taxes2 2 4 4 
Total operating expenses283 269 593 552 
Operating income26 50 65 77 
Other income and (deductions)
Interest expense, net(17)(14)(32)(29)
Other, net2 — 5 2 
Total other income and (deductions)(15)(14)(27)(27)
Income before income taxes11 36 38 50 
Income taxes— (1)1 (1)
Net income$11 $37 $37 $51 
Comprehensive income$11 $37 $37 $51 
See the Combined Notes to Consolidated Financial Statements
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ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED BALANCE SHEETSSTATEMENTS OF CASH FLOWS
(Unaudited)
(In millions)March 31, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$168 $29 
Accounts receivable
Customer accounts receivable177190
Customer allowance for credit losses(49)(49)
Customer accounts receivable, net128 141 
Other accounts receivable7976
Other allowance for credit losses(14)(15)
Other accounts receivable, net65 61 
Receivables from affiliates— 2 
Inventories, net37 36 
Regulatory assets137 61 
Other5 3 
Total current assets540 333 
Property, plant, and equipment (net of accumulated depreciation and amortization of $1,458 and $1,420 as of March 31, 2022 and December 31, 2021, respectively)3,763 3,729 
Deferred debits and other assets
Regulatory assets559 430 
Prepaid pension asset30 27 
Other37 37 
Total deferred debits and other assets626 494 
Total assets$4,929 $4,556 
Six Months Ended
June 30,
(In millions)20222021
Cash flows from operating activities
Net income$37 $51 
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization118 87 
Deferred income taxes and amortization of investment tax credits— (2)
Other non-cash operating activities25 (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 expenses9 (2)
Collateral received, net137 — 
Income taxes8 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 activities221 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 debt175 350 
Retirement of long-term debt— (249)
Dividends paid on common stock(38)(229)
Contributions from parent173 303 
Other financing activities(4)(4)
Net cash flows provided by financing activities162 162 
Increase (decrease) in cash, restricted cash, and cash equivalents204 (7)
Cash, restricted cash, and cash equivalents at beginning of period29 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)
See the Combined Notes to Consolidated Financial Statements
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ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)June 30, 2022December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$233 $29 
Accounts receivable
Customer accounts receivable194190
Customer allowance for credit losses(45)(49)
Customer accounts receivable, net149 141 
Other accounts receivable7076
Other allowance for credit losses(14)(15)
Other accounts receivable, net56 61 
Receivables from affiliates1 2 
Inventories, net38 36 
Prepaid utility taxes40 — 
Regulatory assets135 61 
Other7 3 
Total current assets659 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 assets535 430 
Prepaid pension asset26 27 
Other34 37 
Total deferred debits and other assets595 494 
Total assets$5,052 $4,556 
See the Combined Notes to Consolidated Financial Statements
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Table of Contents
ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED BALANCE SHEETS
(Unaudited)
(In millions)(In millions)March 31, 2022December 31, 2021(In millions)June 30, 2022December 31, 2021
LIABILITIES AND SHAREHOLDER'S EQUITYLIABILITIES AND SHAREHOLDER'S EQUITYLIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilitiesCurrent liabilitiesCurrent liabilities
Short-term borrowingsShort-term borrowings$— $144 Short-term borrowings$— $144 
Long-term debt due within one yearLong-term debt due within one year3 3 Long-term debt due within one year3 3 
Accounts payableAccounts payable139 165 Accounts payable157 165 
Accrued expensesAccrued expenses43 44 Accrued expenses43 44 
Payables to affiliatesPayables to affiliates23 31 Payables to affiliates20 31 
Customer depositsCustomer deposits18 18 Customer deposits18 18 
Regulatory liabilitiesRegulatory liabilities20 28 Regulatory liabilities29 28 
PPA termination obligationPPA termination obligation85 — PPA termination obligation87 — 
OtherOther18 12 Other149 12 
Total current liabilitiesTotal current liabilities349 445 Total current liabilities506 445 
Long-term debtLong-term debt1,754 1,579 Long-term debt1,754 1,579 
Deferred credits and other liabilitiesDeferred credits and other liabilitiesDeferred credits and other liabilities
Deferred income taxes and unamortized investment tax creditsDeferred income taxes and unamortized investment tax credits692 682 Deferred income taxes and unamortized investment tax credits695 682 
Regulatory liabilitiesRegulatory liabilities197 214 
Non-pension postretirement benefit obligationsNon-pension postretirement benefit obligations11 12 Non-pension postretirement benefit obligations10 12 
Regulatory liabilities203 214 
OtherOther165 49 Other143 49 
Total deferred credits and other liabilitiesTotal deferred credits and other liabilities1,071 957 Total deferred credits and other liabilities1,045 957 
Total liabilitiesTotal liabilities3,174 2,981 Total liabilities3,305 2,981 
Commitments and contingenciesCommitments and contingencies00Commitments and contingencies00
Shareholder's equityShareholder's equityShareholder's equity
Common stockCommon stock1,763 1,590 Common stock1,763 1,590 
Retained deficitRetained deficit(8)(15)Retained deficit(16)(15)
Total shareholder's equityTotal shareholder's equity1,755 1,575 Total shareholder's equity1,747 1,575 
Total liabilities and shareholder's equityTotal liabilities and shareholder's equity$4,929 $4,556 Total liabilities and shareholder's equity$5,052 $4,556 

See the Combined Notes to Consolidated Financial Statements
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ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY
(Unaudited)
Three Months Ended March 31, 2022Six Months Ended June 30, 2022
(In millions)(In millions)Common StockRetained DeficitTotal Shareholder's Equity(In millions)Common StockRetained DeficitTotal Shareholder's Equity
Balance, December 31, 2021Balance, December 31, 2021$1,590 $(15)$1,575 Balance, December 31, 2021$1,590 $(15)$1,575 
Net incomeNet income— 26 26 Net income— 26 26 
Common stock dividendsCommon stock dividends— (19)(19)Common stock dividends— (19)(19)
Contributions from parentContributions from parent173 — 173 Contributions from parent173 — 173 
Balance, March 31, 2022Balance, March 31, 2022$1,763 $(8)$1,755 Balance, March 31, 2022$1,763 $(8)$1,755 
Net incomeNet income— 11 11 
Common stock dividendsCommon stock dividends— (19)(19)
Balance, June 30, 2022Balance, June 30, 2022$1,763 $(16)$1,747 

Three Months Ended March 31, 2021Six Months Ended June 30, 2021
(In millions)(In millions)Common StockRetained EarningsTotal Shareholder's Equity(In millions)Common StockRetained Earnings (Deficit)Total Shareholder's Equity
Balance, December 31, 2020Balance, December 31, 2020$1,271 $127 $1,398 Balance, December 31, 2020$1,271 $127 $1,398 
Net incomeNet income— 14 14 Net income— 14 14 
Common stock dividendsCommon stock dividends— (14)(14)Common stock dividends— (14)(14)
Contributions from parentContributions from parent303 — 303 Contributions from parent303 — 303 
Balance, March 31, 2021Balance, March 31, 2021$1,574 $127 $1,701 Balance, March 31, 2021$1,574 $127 $1,701 
Net incomeNet income— 37 37 
Common stock dividendsCommon stock dividends— (215)(215)
Balance, June 30, 2021Balance, June 30, 2021$1,574 $(51)$1,523 

See the Combined Notes to Consolidated Financial Statements
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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 distribution and transmission 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 CompanyPurchase and regulated retail sale of electricityNorthern Illinois, including the City of Chicago
Transmission and distribution of electricity to retail customers
PECO Energy CompanyPurchase and regulated retail sale of electricity and natural gasSoutheastern Pennsylvania, including the City of Philadelphia (electricity)
Transmission and distribution of electricity and distribution of natural gas to retail customersPennsylvania counties surrounding the City of Philadelphia (natural gas)
Baltimore Gas and Electric CompanyPurchase and regulated retail sale of electricity and natural gasCentral 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 LLCUtility services holding company engaged, through its reportable segments Pepco, DPL, and ACEService 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 gasPortions of Delaware and Maryland (electricity)
Transmission and distribution of electricity and distribution of natural gas to retail customersPortions of New Castle County, Delaware (natural gas)
Atlantic City Electric CompanyPurchase and regulated retail sale of electricityPortions 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, 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.
The accompanying consolidated financial statements as of March 31,June 30, 2022 and for the three and six months ended March 31,June 30, 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 disclosed. The
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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, 2021 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. 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, meets 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. See Note 2 — Discontinued Operations for additional information.
Prior Period Adjustments and Reclassifications (Exelon, PHI, ACE)
In the first quarter of 2022, management identified an error related to an overstatement of the regulatory liability associated with ACE’s mechanism to recover the cost of Transition Bonds issued in 2002 and 2003 by ACE Funding. Management has concluded that the error was not material to previously issued financial statements for Exelon, PHI or ACE.
The error was corrected through a revision to ACE’s financial statements contained herein. The impact of the error correction was an $8 million increase to ACE’s opening Retained earnings as of January 1, 2021 with a corresponding reduction to Regulatory liabilities of $11 million and an increase to Deferred income taxes and unamortized investment tax credits of $3 million. The impact of the error to ACE’s Total operating revenues and Net income was less than $1 million for the three months ended March 31, 2021. The error did not impact net cash flows provided by operating activities, net cash flows used in investing activities or net cash flows provided by financing activities for the three months ended March 31, 2021.
The error was corrected in the Exelon and PHI financial statements for the three months ended March 31, 2022 as it was not material, resulting in an increase to Net income of $8 million.
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.
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.
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Note 2 — Discontinued Operations
•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 10 — Debt and Credit Agreements 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.
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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 period from February 1, 2022 to March 31,three months ended June 30, 2022, the amounts Exelon billed Constellation and Constellation billed Exelon for these services were $56$69 million recorded in Other income, net and $9$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 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. Income Taxes for additional information.
In addition, the Utility Registrants will continue to incur expenses from transactions with Generation 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 Generation to provide a portion of ComEd’s electric supply requirements. ComEd also purchased RECs and ZECs from Generation.
•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.
•BGE received a portion of its energy requirements from Generation under its MDPSC-approved market-based SOS and gas commodity programs.
•Pepco received electric supply from Generation under contracts executed through Pepco’s competitive procurement process approved by the MDPSC and DCPSC.
•DPL received a portion of its energy requirements from Generation under its MDPSC and DEPSC approved market-based SOS commodity programs.
•ACE received electric supply from Generation 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 NDT funds are greater than the underlying ARO at the end of decommissioning, such amounts are due back to ComEd and PECO, as applicable, for payment to their respective customers. See Note 109 — Asset Retirement Obligations of the Combined Notes to Consolidated Financial Statements of the Exelon 2021 Recast Form 10-K and Note 15 — Related Party Transactions for additional information.
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(Dollars in millions, except per share data, unless otherwise noted)

Note 2 — Discontinued Operations
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.
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 March 31,June 30, 2022 and March 31,June 30, 2021.
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
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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
March 31,		Three Months Ended
June 30,		Six Months Ended
June 30,
20222021202120222021
Operating revenuesOperating revenuesOperating revenues
Competitive business revenuesCompetitive business revenues$1,855 $5,265 Competitive business revenues$3,900 $1,855 $9,165 
Competitive business revenues from affiliatesCompetitive business revenues from affiliates161 294 Competitive business revenues from affiliates255 161 549 
Total operating revenuesTotal operating revenues2,016 5,559 Total operating revenues4,155 2,016 9,714 
Operating expensesOperating expensesOperating expenses
Competitive businesses purchased power and fuelCompetitive businesses purchased power and fuel1,138 4,610 Competitive businesses purchased power and fuel1,947 1,138 6,557 
Operating and maintenance(a)
Operating and maintenance(a)
371 904 
Operating and maintenance(a)
1,382 371 2,287 
Depreciation and amortizationDepreciation and amortization94 940 Depreciation and amortization930 94 1,869 
Taxes other than income taxesTaxes other than income taxes44 121 Taxes other than income taxes118 44 239 
Total operating expensesTotal operating expenses1,647 6,575 Total operating expenses4,377 1,647 10,952 
Gain on sales of assets and businessesGain on sales of assets and businesses10 71 Gain on sales of assets and businesses8 10 79 
Operating income (loss)Operating income (loss)379 (945)Operating income (loss)(214)379 (1,159)
Other income and (deductions)Other income and (deductions)Other income and (deductions)
Interest expense, netInterest expense, net(20)(68)Interest expense, net(72)(20)(140)
Other, netOther, net(281)167 Other, net508 (281)675 
Total other income and (deductions)Total other income and (deductions)(301)99 Total other income and (deductions)436 (301)535 
Income (loss) before income taxesIncome (loss) before income taxes78 (846)Income (loss) before income taxes222 78 (624)
Income taxesIncome taxes(40)(58)Income taxes71 (40)13 
Equity in losses of unconsolidated affiliatesEquity in losses of unconsolidated affiliates(1)(1)Equity in losses of unconsolidated affiliates(1)(1)(3)
Net income (loss)Net income (loss)117 (789)Net income (loss)150 117 (640)
Net income attributable to noncontrolling interestsNet income attributable to noncontrolling interests1 25 Net income attributable to noncontrolling interests75 1 99 
Net income (loss) from discontinued operationsNet income (loss) from discontinued operations$116 $(814)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:
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Note 2 — Discontinued Operations
__________
(a)Includes transaction and transition costs related to the separation of $52 million and $3 million for the three months ended March 31, 2022 and 2021, respectively. $50 million and $2 million of transaction costs and $2 million and less than $1 million of transition costs are included in the results of discontinued operations in the table presented above for the three months ended March 31, 2022 and March 31, 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 March 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 three months ended March 31, 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:
December 31, 2021
ASSETS
Current assets
Cash and cash equivalents$510 
Restricted cash and cash equivalents72 
Accounts receivable
Customer accounts receivable1,724
Customer allowance for credit losses(55)
Customer accounts receivable, net1,669 
Other accounts receivable596
Other allowance for credit losses(4)
Other accounts receivable, net592 
Mark-to-market derivative assets2,169 
Inventories, net
Fossil fuel and emission allowances284 
Materials and supplies1,004 
Renewable energy credits529 
Assets held for sale13 
Other993 
Total current assets of discontinued operations7,835 
Property, plant, and equipment (net of accumulated depreciation and amortization of $15,888)19,661 
Deferred debits and other assets
Nuclear decommissioning trust funds15,938 
Investments193 
Mark-to-market derivative assets949 
Other1,768 
Total property, plant, and equipment, deferred debits, and other assets of discontinued operations38,509 
Total assets of discontinued operations$46,344 
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Note 2 — Discontinued Operations
December 31, 2021
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities
Short-term borrowings$2,082 
Long-term debt due within one year1,220 
Accounts payable1,757 
Accrued expenses818 
Mark-to-market derivative liabilities981 
Renewable energy credit obligation779 
Liabilities held for sale3 
Other300 
Total current liabilities of discontinued operations7,940 
Long-term debt4,575 
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits3,583 
Asset retirement obligations12,819 
Pension obligations939 
Non-pension postretirement benefit obligations876 
Spent nuclear fuel obligation1,210 
Mark-to-market derivative liabilities513 
Other1,161 
Total long-term debt, deferred credits, and other liabilities of discontinued operations25,676 
Total liabilities of discontinued operations$33,616 
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 threesix months ended March 31,June 30, 2022 and March 31,June 30, 2021.
Three Months Ended March 31, 2022Six Months Ended
June 30,
2022202120222021
Non-cash items included in net income (loss) from discontinued operations:Non-cash items included in net income (loss) from discontinued operations:Non-cash items included in net income (loss) from discontinued operations:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortizationDepreciation, amortization, and accretion, including nuclear fuel and energy contract amortization$207 $1,346 Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization$207 $2,686 
Asset impairmentsAsset impairments— 493 
Gain on sales of assets and businessesGain on sales of assets and businesses9 (71)Gain on sales of assets and businesses9 (79)
Deferred income taxes and amortization of investment tax creditsDeferred income taxes and amortization of investment tax credits(143)(234)Deferred income taxes and amortization of investment tax credits(143)(268)
Net fair value changes related to derivativesNet fair value changes related to derivatives(59)(178)Net fair value changes related to derivatives(59)(490)
Net realized and unrealized losses (gains) on NDT fund investmentsNet realized and unrealized losses (gains) on NDT fund investments205 (118)Net realized and unrealized losses (gains) on NDT fund investments205 (376)
Net unrealized losses on equity investments16 23 
Net unrealized losses (gains) on equity investmentsNet unrealized losses (gains) on equity investments16 (96)
Other decommissioning-related activityOther decommissioning-related activity36 (332)Other decommissioning-related activity36 (636)
Cash flows from investing activities:Cash flows from investing activities:Cash flows from investing activities:
Capital expendituresCapital expenditures(227)(394)Capital expenditures(227)(731)
Collection of DPPCollection of DPP169 1,574 Collection of DPP169 2,209 
Supplemental cash flow information:Supplemental cash flow information:Supplemental cash flow information:
Decrease in capital expenditures not paidDecrease in capital expenditures not paid(128)(37)Decrease in capital expenditures not paid(128)(66)
Increase in DPPIncrease in DPP348 1,339 Increase in DPP348 1,958 
Increase in PP&E related to ARO updateIncrease in PP&E related to ARO update335 — Increase in PP&E related to ARO update335 — 
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Note 3 — Regulatory Matters
3. Regulatory Matters (All Registrants)
As discussed in Note 3 — Regulatory Matters of the Exelon 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/JurisdictionFiling DateServiceRequested Revenue Requirement IncreaseApproved Revenue Requirement IncreaseApproved ROEApproval DateRate Effective Date
ComEd - Illinois(a)
April 16, 2021Electric$51 $46 7.36 %December 1, 2021January 1, 2022
PECO - PennsylvaniaMarch 30, 2021Electric246 132 
N/A(b)
November 18, 2021January 1, 2022
BGE - Maryland(c)
May 15, 2020 (amended September 11, 2020)Electric203 140 9.50 %December 16, 2020January 1, 2021
Natural Gas108 74 9.65 %
Pepco - District of Columbia(d)
May 30, 2019 (amended June 1, 2020)Electric136 109 9.275 %June 8, 2021July 1, 2021
Pepco - Maryland(e)
October 26, 2020 (amended March 31, 2021)Electric104 52 9.55 %June 28, 2021June 28, 2021
DPL - Maryland(f)
September 1, 2021 (amended December 23, 2021)Electric27 13 9.60 %March 2, 2022March 2, 2022
ACE - New Jersey(g)
December 9, 2020 (amended February 26, 2021)Electric67 41 9.60 %July 14, 2021January 1, 2022
__________
(a)ComEd's 2022 approved revenue requirement reflects an increase of $37 million for the initial year revenue requirement for 2022 and an increase of $9 million related to the annual reconciliation for 2020. The revenue requirement for 2022 provides for a weighted average debt and equity return on distribution rate base of 5.72%, inclusive of an allowed ROE of 7.36%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points. The reconciliation revenue requirement for 2020 provides for a weighted average debt and equity return on distribution rate base of 5.69%, inclusive of an allowed ROE of 7.29%, reflecting the monthly yields on 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points.
(b)The PECO electric 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. 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. Whether certain tax benefits will be used to offset the customer rate increases in 2023 has not been decided, and BGE cannot predict the outcome.
(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.
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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)The approved settlement reflects a 9.60% ROE, which is solely for the purposes of calculating AFUDC and regulatory asset carrying costs.
(g)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 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.
Pending Distribution Base Rate Case Proceedings
Registrant/JurisdictionRegistrant/JurisdictionFiling DateServiceRequested Revenue Requirement IncreaseRequested ROEExpected Approval TimingRegistrant/JurisdictionFiling DateServiceRequested Revenue Requirement IncreaseRequested ROEExpected Approval Timing
ComEd - Illinois(a)
ComEd - Illinois(a)
April 15, 2022Electric$199 7.85 %Fourth quarter of 2022
ComEd - Illinois(a)
April 15, 2022Electric$199 7.85 %Fourth quarter of 2022
PECO - PennsylvaniaPECO - PennsylvaniaMarch 31, 2022Natural Gas82 10.95 %Fourth quarter of 2022PECO - PennsylvaniaMarch 31, 2022Natural Gas82 10.95 %Fourth quarter of 2022
DPL - Delaware(b)
DPL - Delaware(b)
January 14, 2022 (amended February 28, 2022)Natural Gas15 10.30 %First quarter of 2023
DPL - Delaware(b)
January 14, 2022 (amended February 28, 2022)Natural Gas15 10.30 %First quarter of 2023
DPL - Maryland(c)
DPL - Maryland(c)
May 19, 2022Electric38 10.25 %Fourth quarter of 2022
__________
(a)ComEd's 2023 requested revenue requirement reflects an increase of $144 million for the initial year revenue requirement for 2023 and an increase of $55 million related to the annual reconciliation for 2021. The revenue requirement for 2023 provides for a weighted average debt and equity return on distribution rate base of 5.94%, inclusive of an allowed ROE of 7.85%, reflecting the average monthly yields for 30-year treasury bonds plus 580 basis points. The reconciliation revenue requirement for 2021 provides for a weighted average debt and equity return on distribution 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 result of the law authorizing the rate setting process sunsetting at the end of 2022. See Note 3.3 - Regulatory Matters of the Exelon 2021 Recast Form 10-K for additional information on ComEd's transition away from the electric distribution formula rate.
(b)The rates will go into effect on August 14, 2022, subject to refund.
(c)Reflects a three-year cumulative multi-year plan for January 1, 2023 to December 31, 2025 and total requested revenue requirement increases, before offsets, of $23 million effective January 1, 2023, $8 million effective January 1, 2024, and $7 million effective January 1, 2025, to recover capital investments made in 2021 and planned capital investments through the end of 2025. DPL is proposing the acceleration of refunds for certain tax benefits to partially offset the customer rate increases by $12 million and $8 million in 2023 and 2024, respectively.
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).
For 2022, the following total increases were included in ComEd’s and BGE's electric transmission formula rate update. PECO, Pepco, DPL, and ACE intend to file by the required deadline for the annual update.
Registrant(a)
Initial Revenue Requirement IncreaseAnnual Reconciliation DecreaseTotal Revenue Requirement Increase
Allowed Return on Rate Base(c)
Allowed ROE(d)
ComEd$24 $(24)$— 8.11 %11.50 %
BGE25 (4)16 (b)7.30 %10.50 %
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Note 3 — Regulatory Matters
For 2022, the following total increases/(decreases) were included in the Utility Registrants' electric transmission formula rate update:
Registrant(a)
Initial Revenue Requirement IncreaseAnnual Reconciliation (Decrease) IncreaseTotal Revenue Requirement Increase
Allowed Return on Rate Base(b)
Allowed ROE(c)
ComEd$24 $(24)$— 8.11 %11.50 %
PECO23 16 39 7.30 %10.35 %
BGE25 (4)16 (d)7.30 %10.50 %
Pepco16 15 31 7.60 %10.50 %
DPL9 2 11 7.09 %10.50 %
ACE21 13 34 7.18 %10.50 %
__________
(a)All rates are effective June 1, 2022 - May 31, 2023, subject to review by interested parties pursuant to review protocols of ComEd's and BGE'seach Utility Registrants' tariff.
(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 million reduction related to a FERC-approved dedicated facilities charge to recover the costs of providing transmission service to specifically designated load by BGE.
(c)Represents the weighted average debt and equity return on transmission rate bases.
(d)As part of the FERC-approved settlements of ComEd’s 2007 transmission rate case, the rate of return on common equity is 11.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO, and the common equity component of the ratio used to calculate the weighted average debt and equity return for the transmission formula rate is currently capped at 55%. As part of the FERC-approved settlement of the ROE complaint against BGE, the rate of return on common equity is 10.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO.
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 plan 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") 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.
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 between June 1, 2022 and May 31, 2027 and all its costs of doing so will be recovered through a new rider. 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 million as of June 30, 2022 for the difference between customer credits issued and the credit to be received from the participating nuclear plants.
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Note 3 — Regulatory Matters
Excess Deferred Income Taxes
The ICC initiated a docket to accelerate and fully credit to customers TCJA unprotected property-related EDIT no later than December 31, 2025. On April 13,July 7, 2022, the ICC issued a stipulation and agreementfinal order on the schedule for the acceleration of EDIT amortization, wasadopting the proposal as submitted by several parties, including ComEd, ICC Staff, the Illinois Attorney General's Office, and the Citizens Utility Board. EDIT amortization will be credited to customers through a new rider from January 1, 2023 through December 31, 2025.
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, 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 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 expected to be issued by the ICC no later than the first quarter of 2023. At this time, ComEd cannot predict anthe outcome of these proceedings.

See Note 3 — Regulatory Matters of the Exelon 2021 Recast Form 10-K for additional information on CEJA (referred to as Clean Energy Law).
Energy Efficiency Formula Rate (Exelon and ComEd). ComEd filed its annual energy efficiency formula rate update with the 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 on a reconciliation of the 2021 actual costs plus projected 2023 expenditures.
Initial Revenue Requirement IncreaseAnnual Reconciliation DecreaseTotal 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 on 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.
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 March 31,June 30, 2022, the $203$180 million liability for the contract termination fee consists of $85$87 million and $118$93 million included in Other current liabilities and Other deferred credits and other liabilities, respectively, in Exelon's Consolidated Balance Sheet. As of March 31, 2022, theThe current and noncurrent liability is included in PPA termination obligation and Other deferred credits and other liabilities, respectively, in PHI's and ACE's Consolidated Balance Sheets.
Regulatory Assets and Liabilities
The Utility Registrants' regulatory For the six months ended June 30, 2022, ACE has paid $23 million of the liability, which is recorded in Changes in Other assets and liabilities have not changed materially since December 31, 2021, unless noted below. See Note 3 — Regulatory Mattersin Exelon's, PHI's, and ACE's Consolidated Statements of the Exelon 2021 Form 10-K for additional information on the specific regulatory assets and liabilities.Cash Flows.
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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 3 — Regulatory Matters
Regulatory Assets and Liabilities
PECO.The Utility Registrants' regulatory assets and liabilities have not changed materially since December 31, 2021, unless noted below. See Note 3 — Regulatory Matters of the 2021 Recast Form 10-K for additional information on the specific regulatory assets and liabilities.
ComEd. Regulatory assets increased $66$254 million primarily due to an increase of $60$255 million in the CMC regulatory asset, as discussed in CEJA above, $89 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 million primarily due to an increase of $99 million in the Deferred Income Taxes regulatory asset. Regulatory liabilities decreased by $112$325 million primarily due to a decrease of $111$305 million in the Nuclear Decommissioning the Regulatory Agreement Units regulatory liability and $12 million in the Electric Energy and Natural Gas Costs regulatory liability.
BGE.Regulatory assets decreased $50$49 million primarily due to a decrease of $19$20 million in the Under-recovered revenue decoupling regulatory asset, $14 million in the Electric Energy and Natural Gas Costs regulatory asset, and $16$13 million in the Energy Efficiency and Demand Response Programs regulatory asset.
Pepco. Regulatory assets decreased $47 million primarily due to a decrease of $20 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 $53$44 million primarily due to a decrease of $65$46 million in the Deferred Income Taxes regulatory liability.
ACE. Regulatory assets increased $205$179 million primarily due to an increase in the Electric Energy Costs regulatory asset as a result of the PPA termination. Regulatory liabilities decreased $19$16 million primarily due to a decrease of $9$13 million in the Deferred Income Taxes regulatory liability and $5 million in the Electric Energy Costs 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.
Exelon
ComEd(a)
PECO
BGE(b)
PHI
Pepco(c)
DPL(c)
ACEExelon
ComEd(a)
PECO
BGE(b)
PHI
Pepco(c)
DPL(c)
ACE
March 31, 2022$49 $2 $— $34 $13 $11 $2 $— 
June 30, 2022June 30, 2022$49 $4 $— $32 $13 $11 $2 $— 
December 31, 2021December 31, 202143 1 — 37 5 3 2 — December 31, 202143 1 — 37 5 3 2 — 
__________
(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 authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholder's investment on its 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.

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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 Exelon 2021 Recast 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 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.
Revenues recognized were immaterial for Exelon, PHI, Pepco, DPL,The following table provides a rollforward of the contract liabilities reflected in Exelon's, PHI's, Pepco's, DPL's, and ACEACE's Consolidated Balance Sheets for the three and six months ended March 31,June 30, 2022 and 2021. As of March 31,June 30, 2022 and December 31, 2021, ComEd's, PECO's, and BGE's contract liabilities were immaterial.
58
Exelon(a)
PHI(a)
Pepco(a)
DPL
ACE(a)
Balance as of December 31, 2021$109 $109 $87 $11 $11 
Revenues recognized(2)(2)(2)— — 
Balance as of March 31, 2022107 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, 2021116 116 92 12 12 
Revenues recognized(3)(3)(1)(1)(1)
Balance as of June 30, 2021$113 $113 $91 $11 $11 

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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (a)— (Continued)
(DollarsRevenues recognized in millions, except per share data, unless otherwise noted)

the three and six months ended June 30, 2022 and 2021, were included in the contract liabilities at December 31, 2021 and 2020, respectively.
Note 4 — Revenue from Contracts with Customers
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 March 31,June 30, 2022. 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.
20222023202420252026 and thereafterTotal
Exelon$6 $8 $6 $5 $82 $107 
PHI6 8 6 5 82 107 
Pepco4 6 5 5 65 85 
DPL1 1 — — 9 11 
ACE1 1 1 — 8 11 
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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 4 — Revenue from Contracts with Customers
20222023202420252026 and thereafterTotal
Exelon$4 $8 $6 $5 $82 $105 
PHI4 8 6 5 82 105 
Pepco3 6 5 5 65 84 
DPL1 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's 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 6 reportable segments, which include ComEd, PECO, BGE, and PHI's 3 reportable segments consisting of Pepco, DPL, and ACE. ComEd, PECO, BGE, Pepco, DPL, and ACE each represent a single reportable segment, and as such, no separate segment information is provided for these Registrants. Exelon, ComEd, PECO, BGE, Pepco, DPL, and ACE's CODMs evaluate the performance of and allocate resources to ComEd, PECO, BGE, Pepco, DPL, and ACE based on net income.
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 March 31,June 30, 2022 and 2021 is as follows:
















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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 5 — Segment Information
Three Months Ended March 31,June 30, 2022 and 2021
ComEdPECOBGEPHI
Other(a)
Intersegment
Eliminations		ExelonComEdPECOBGEPHI
Other(a)
Intersegment
Eliminations		Exelon
Operating revenues(b):
Operating revenues(b):
Operating revenues(b):
202220222022
Electric revenuesElectric revenues$1,734 $741 $736 $1,318 $— $(7)$4,522 Electric revenues$1,425 $708 $629 $1,182 $— $(6)$3,938 
Natural gas revenuesNatural gas revenues— 306 418 83 — (2)$805 Natural gas revenues— 108 157 37 — (1)301 
Shared service and other revenuesShared service and other revenues— — — 3 576 (579)$— Shared service and other revenues— — — 2 384 (386)— 
Total operating revenuesTotal operating revenues$1,734 $1,047 $1,154 $1,404 $576 $(588)$5,327 Total operating revenues$1,425 $816 $786 $1,221 $384 $(393)$4,239 
202120212021
Electric revenuesElectric revenues$1,535 $661 $632 $1,170 $— $(7)$3,991 Electric revenues$1,517 $610 $558 $1,113 $— $(9)$3,789 
Natural gas revenuesNatural gas revenues— 228 342 71 — — 641 Natural gas revenues— 83 124 24 — — 231 
Shared service and other revenuesShared service and other revenues— — — 3 491 (494)— Shared service and other revenues— — — 3 524 (527)— 
Total operating revenuesTotal operating revenues$1,535 $889 $974 $1,244 $491 $(501)$4,632 Total operating revenues$1,517 $693 $682 $1,140 $524 $(536)$4,020 
Intersegment revenues(c):
Intersegment revenues(c):
Intersegment revenues(c):
20222022$6 $1 $7 $3 $576 $(587)$6 2022$3 $1 $3 $2 $384 $(393)$— 
202120216 2 6 3 487 (497)7 20215 2 7 4 522 (535)5 
Depreciation and amortization:Depreciation and amortization:Depreciation and amortization:
20222022$321 $92 $171 $218 $15 $— $817 2022$328 $93 $152 $240 $16 $1 $830 
20212021292 86 152 210 17 — 757 2021296 87 141 194 18 — 736 
Operating expenses:Operating expenses:Operating expenses:
20222022$1,406 $793 $919 $1,215 $625 $(531)$4,427 2022$1,039 $639 $717 $1,066 $460 $(378)$3,543 
202120211,210 679 752 1,058 448 (339)3,808 20211,196 552 620 955 495 (374)3,444 
Interest expense, net:Interest expense, net:Interest expense, net:
20222022$100 $41 $35 $69 $93 $— $338 2022$104 $43 $36 $73 $101 $1 $358 
2021202196 38 34 67 83 — 318 202198 42 34 67 83 — 324 
Income (loss) from continuing operations before income taxes:Income (loss) from continuing operations before income taxes:Income (loss) from continuing operations before income taxes:
20222022$240 $220 $207 $137 $(62)$(43)$699 2022$293 $142 $38 $101 $(62)$(1)$511 
20212021236 177 196 136 (32)(149)564 2021238 106 37 138 (46)(144)329 
Income Taxes:Income Taxes:Income Taxes:
20222022$52 $14 $9 $7 $146 $(10)$218 2022$66 $9 $1 $1 $(31)$— $46 
2021202139 10 (13)8 7 (12)39 202146 2 (8)(3)(27)(7)3 
Net income (loss) from continuing operations:Net income (loss) from continuing operations:Net income (loss) from continuing operations:
20222022$188 $206 $198 $130 $(208)$(33)$481 2022$227 $133 $37 $100 $(31)$(1)$465 
20212021197 167 209 128 (39)(137)525 2021192 104 45 141 (19)(137)326 
Capital Expenditures:Capital Expenditures:Capital Expenditures:
20222022$617 $344 $303 $409 $22 $— $1,695 2022$591 $314 $275 $367 $38 $— $1,585 
20212021613 295 336 456 46 — 1,746 2021549 282 284 433 15 — 1,563 
Total assets:
March 31, 2022$37,013 $14,113 $12,509 $25,636 $7,583 $(4,156)$92,698 
December 31, 202136,470 13,824 12,324 24,744 7,634 (8,319)86,677 
__________
(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.
(c)See Note 15 — Related Party Transactions for additional information on intersegment revenues.

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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 5 — Segment Information
PHI:
PepcoDPLACE
Other(a)
Intersegment
Eliminations		PHI
Operating revenues(b):
2022
Electric revenues$581 $295 $309 $— $(3)$1,182 
Natural gas revenues— 37 — — — 37 
Shared service and other revenues— — — 98 (96)2 
Total operating revenues$581 $332 $309 $98 $(99)$1,221 
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):
2022$2 $2 $1 $98 $(101)$2 
20211 2 1 95 (95)4 
Depreciation and amortization:
2022$105 $56 $72 $7 $— $240 
202196 51 40 7 — 194 
Operating expenses:
2022$487 $296 $283 $99 $(99)$1,066 
2021429 255 269 97 (95)955 
Interest expense, net:
2022$38 $17 $17 $1 $— $73 
202135 16 14 2 — 67 
Income (loss) before income taxes:
2022$69 $23 $11 $(2)$— $101 
202172 31 36 (1)— 138 
Income Taxes:
2022$(1)$2 $— $— $— $1 
2021(3)1 (1)— — (3)
Net income (loss):
2022$70 $21 $11 $(2)$— $100 
202175 30 37 (1)— 141 
Capital Expenditures:
2022$184 $91 $92 $— $— $367 
2021219 99 116 (1)— 433 
__________
(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.

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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Table of Contents
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 customersComEdPECOBGEPHIPepcoDPLACE
Electric revenues
Residential$819 $431 $334 $548 $234 $155 $159 
Small commercial & industrial312 126 70 140 35 51 54 
Large commercial & industrial11 72 129 332 250 30 52 
Public authorities & electric railroads5 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 
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Table of Contents
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
Revenues from contracts with customersComEdPECOBGEPHIPepcoDPLACE
Electric revenues
Residential$759 $383 $299 $537 $223 $147 $167 
Small commercial & industrial377 99 60 124 32 46 46 
Large commercial & industrial138 59 108 257 188 22 47 
Public authorities & electric railroads11 8 7 17 10 3 4 
Other(a)
214 54 87 139 50 46 43 
Total electric revenues(b)
$1,499 $603 $561 $1,074 $503 $264 $307 
Natural gas revenues
Residential$— $55 $81 $12 $— $12 $— 
Small commercial & industrial— 22 13 6 — 6 — 
Large commercial & industrial— — 27 1 — 1 — 
Transportation— 5 — 3 — 3 — 
Other(c)
— 1 6 2 — 2 — 
Total natural gas revenues(d)
$— $83 $127 $24 $— $24 $— 
Total revenues from contracts with customers$1,499 $686 $688 $1,098 $503 $288 $307 
Other revenues
Revenues from alternative revenue programs$9 $7 $(10)$41 $19 $10 $12 
Other electric revenues(e)
9 — 3 1 1 — — 
Other natural gas revenues(e)
— — 1 — — — — 
Total other revenues$18 $7 $(6)$42 $20 $10 $12 
Total revenues for reportable segments$1,517 $693 $682 $1,140 $523 $298 $319 
__________
(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:
•$3 million, $5 million at ComEd
•$1 million, $1 million at PECO
•$2 million, $4 million at BGE
•$2 million, $4 million at PHI
•$2 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 2022 and 2021 respectively of:
•less than $1 million, less than $1 million at PECO
•$1 million, $3 million at BGE
(e)Includes late payment charge revenues.

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Table of Contents
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
ComEdPECOBGEPHI
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 
202111 4 13 7 1,010 (1,033)12 
Depreciation and amortization:
2022$649 $185 $322 $459 $32 $— $1,647 
2021589 173 293 404 35 — 1,494 
Operating expenses:
2022$2,444 $1,432 $1,636 $2,282 $1,086 $(909)$7,971 
20212,406 1,231 1,372 2,013 943 (713)7,252 
Interest expense, net:
2022$204 $84 $71 $143 $195 $— $697 
2021193 80 67 134 169 — 643 
Income (loss) from continuing operations before income taxes:
2022$534 $363 $244 $238 $(125)$(45)$1,209 
2021475 283 233 273 (80)(292)892 
Income Taxes:
2022$119 $24 $10 $8 $114 $(12)$263 
202185 12 (21)5 (19)(20)42 
Net income (loss) from continuing operations:
2022$415 $339 $234 $230 $(239)$(33)$946 
2021390 271 254 269 (61)(272)851 
Capital Expenditures:
2022$1,208 $658 $578 $776 $60 $— $3,280 
20211,162 577 620 889 61 — 3,309 
Total assets:
June 30, 2022$37,194 $14,216 $13,093 $25,592 $6,345 $(4,145)$92,295 
December 31, 202136,470 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.
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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:
PepcoDPLACE
Other(a)
Intersegment
Eliminations		PHIPepcoDPLACE
Other(a)
Intersegment
Eliminations		PHI
Operating revenues(b):
Operating revenues(b):
Operating revenues(b):
202220222022
Electric revenuesElectric revenues$614 $348 $349 $— $7 $1,318 Electric revenues$1,195 $643 $658 $— $5 $2,501 
Natural gas revenuesNatural gas revenues— 83 — — — 83 Natural gas revenues— 120 — — — 120 
Shared service and other revenuesShared service and other revenues— — — 107 (104)3 Shared service and other revenues— — — 205 (200)5 
Total operating revenuesTotal operating revenues$614 $431 $349 $107 $(97)$1,404 Total operating revenues$1,195 $763 $658 $205 $(195)$2,626 
202120212021
Electric revenuesElectric revenues$553 $311 $310 $— $(4)$1,170 Electric revenues$1,076 $585 $629 $— $(7)$2,283 
Natural gas revenuesNatural gas revenues— 71 — — — 71 Natural gas revenues— 95 — — — 95 
Shared service and other revenuesShared service and other revenues— — — 95 (92)3 Shared service and other revenues— — — 189 (183)6 
Total operating revenuesTotal operating revenues$553 $382 $310 $95 $(96)$1,244 Total operating revenues$1,076 $680 $629 $189 $(190)$2,384 
Intersegment revenues(c):
Intersegment revenues(c):
Intersegment revenues(c):
20222022$1 $1 $1 $97 $(97)$3 2022$2 $3 $2 $195 $(196)$6 
202120211 2 1 95 (96)3 20213 4 1 189 (190)7 
Depreciation and amortization:Depreciation and amortization:Depreciation and amortization:
20222022$108 $57 $47 $6 $— $218 2022$213 $113 $118 $15 $— $459 
20212021102 53 47 8 — 210 2021199 104 87 14 — 404 
Operating expenses:Operating expenses:Operating expenses:
20222022$547 $357 $311 $97 $(97)$1,215 2022$1,034 $653 $593 $197 $(195)$2,282 
20212021466 309 282 97 (96)1,058 2021895 564 552 192 (190)2,013 
Interest expense, net:Interest expense, net:Interest expense, net:
20222022$36 $16 $14 $3 $— $69 2022$74 $33 $32 $5 $(1)$143 
2021202134 15 15 3 — 67 202169 30 29 6 — 134 
Income (loss) before income taxes:Income (loss) before income taxes:Income (loss) before income taxes:
20222022$44 $60 $27 $6 $— $137 2022$113 $83 $38 $4 $— $238 
2021202165 61 14 (4)— 136 2021137 92 50 (6)— 273 
Income Taxes:Income Taxes:Income Taxes:
20222022$(2)$4 $1 $4 $— $7 2022$(3)$6 $1 $4 $— $8 
202120216 5 — (3)— 8 20213 6 (1)(3)— 5 
Net income (loss):Net income (loss):Net income (loss):
20222022$46 $56 $26 $2 $— $130 2022$116 $77 $37 $— $— $230 
2021202159 56 14 (1)— 128 2021134 86 51 (2)— 269 
Capital Expenditures:Capital Expenditures:Capital Expenditures:
20222022$218 $103 $87 $1 $— $409 2022$402 $194 $179 $1 $— $776 
20212021220 112 123 1 — 456 2021439 211 239 — — 889 
Total assets:Total assets:Total assets:
March 31, 2022$10,458 $5,573 $4,929 $4,720 $(44)$25,636 
June 30, 2022June 30, 2022$10,226 $5,742 $5,052 $4,775 $(203)$25,592 
December 31, 2021December 31, 20219,903 5,412 4,556 4,933 (60)24,744 December 31, 20219,903 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.
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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.
Three Months Ended March 31, 2022Six Months Ended June 30, 2022
Revenues from contracts with customersRevenues from contracts with customersComEdPECOBGEPHIPepcoDPLACERevenues from contracts with customersComEdPECOBGEPHIPepcoDPLACE
Electric revenuesElectric revenuesElectric revenues
ResidentialResidential$857 $487 $417 $652 $275 $207 $170 Residential$1,675 $918 $752 $1,200 $509 $362 $329 
Small commercial & industrialSmall commercial & industrial423 111 81 141 38 56 47 Small commercial & industrial736 237 151 281 73 107 101 
Large commercial & industrialLarge commercial & industrial153 64 131 323 253 26 44 Large commercial & industrial165 136 260 655 503 56 96 
Public authorities & electric railroadsPublic authorities & electric railroads14 8 7 16 8 4 4 Public authorities & electric railroads20 15 14 31 16 7 8 
Other(a)
Other(a)
239 62 97 193 46 56 81 
Other(a)
472 130 196 359 100 113 136 
Total electric revenues(b)
Total electric revenues(b)
$1,686 $732 $733 $1,325 $620 $349 $346 
Total electric revenues(b)
$3,068 $1,436 $1,373 $2,526 $1,201 $645 $670 
Natural gas revenuesNatural gas revenuesNatural gas revenues
ResidentialResidential$— $218 $282 $51 $— $51 $— Residential$— $289 $378 $68 $— $68 $— 
Small commercial & industrialSmall commercial & industrial— 76 45 21 — 21 — Small commercial & industrial— 105 63 29 — 29 — 
Large commercial & industrialLarge commercial & industrial— — 65 3 — 3 — Large commercial & industrial— — 100 6 — 6 — 
TransportationTransportation— 8 — 4 — 4 — Transportation— 14 — 7 — 7 — 
Other(c)
Other(c)
— 3 35 4 — 4 — 
Other(c)
— 5 47 10 — 10 — 
Total natural gas revenues(d)
Total natural gas revenues(d)
$— $305 $427 $83 $— $83 $— 
Total natural gas revenues(d)
$— $413 $588 $120 $— $120 $— 
Total revenues from contracts with customersTotal revenues from contracts with customers$1,686 $1,037 $1,160 $1,408 $620 $432 $346 Total revenues from contracts with customers$3,068 $1,849 $1,961 $2,646 $1,201 $765 $670 
Other revenuesOther revenuesOther revenues
Revenues from alternative revenue programsRevenues from alternative revenue programs$40 $6 $(12)$(5)$(7)$(1)$3 Revenues from alternative revenue programs$75 $6 $(32)$(22)$(7)$(3)$(12)
Other electric revenues(e)
Other electric revenues(e)
8 3 4 1 1 — — 
Other electric revenues(e)
15 7 8 2 1 1 — 
Other natural gas revenues(e)
Other natural gas revenues(e)
— 1 2 — — — — 
Other natural gas revenues(e)
— 1 3 — — — — 
Total other revenuesTotal other revenues$48 $10 $(6)$(4)$(6)$(1)$3 Total other revenues$90 $14 $(21)$(20)$(6)$(2)$(12)
Total revenues for reportable segmentsTotal revenues for reportable segments$1,734 $1,047 $1,154 $1,404 $614 $431 $349 Total revenues for reportable segments$3,158 $1,863 $1,940 $2,626 $1,195 $763 $658 
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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 5 — Segment Information
Three Months Ended March 31, 2021Six Months Ended June 30, 2021
Revenues from contracts with customersRevenues from contracts with customersComEdPECOBGEPHIPepcoDPLACERevenues from contracts with customersComEdPECOBGEPHIPepcoDPLACE
Electric revenuesElectric revenuesElectric revenues
ResidentialResidential$741 $433 $362 $605 $253 $190 $162 Residential$1,502 $816 $662 $1,142 $476 $337 $329 
Small commercial & industrialSmall commercial & industrial367 100 69 118 33 46 39 Small commercial & industrial744 199 129 242 65 92 85 
Large commercial & industrialLarge commercial & industrial134 57 105 248 184 21 43 Large commercial & industrial271 116 213 505 372 43 90 
Public authorities & electric railroadsPublic authorities & electric railroads11 9 7 13 6 4 3 Public authorities & electric railroads22 17 13 30 16 7 7 
Other(a)
Other(a)
220 52 77 143 51 41 52 
Other(a)
433 106 165 283 101 87 95 
Total electric revenues(b)
Total electric revenues(b)
$1,473 $651 $620 $1,127 $527 $302 $299 
Total electric revenues(b)
$2,972 $1,254 $1,182 $2,202 $1,030 $566 $606 
Natural gas revenuesNatural gas revenuesNatural gas revenues
ResidentialResidential$— $160 $216 $46 $— $46 $— Residential$— $215 $297 $57 $— $57 $— 
Small commercial & industrialSmall commercial & industrial— 59 35 18 — 18 — Small commercial & industrial— 81 48 24 — 24 — 
Large commercial & industrialLarge commercial & industrial— — 54 2 — 2 — Large commercial & industrial— — 81 3 — 3 — 
TransportationTransportation— 7 — 4 — 4 — Transportation— 12 — 8 — 8 — 
Other(c)
Other(c)
— 2 31 1 — 1 — 
Other(c)
— 3 36 2 — 3 — 
Total natural gas revenues(d)
Total natural gas revenues(d)
$— $228 $336 $71 $— $71 $— 
Total natural gas revenues(d)
$— $311 $462 $94 $— $95 $— 
Total revenues from contracts with customersTotal revenues from contracts with customers$1,473 $879 $956 $1,198 $527 $373 $299 Total revenues from contracts with customers$2,972 $1,565 $1,644 $2,296 $1,030 $661 $606 
Other revenuesOther revenuesOther revenues
Revenues from alternative revenue programsRevenues from alternative revenue programs$54 $10 $18 $46 $26 $9 $11 Revenues from alternative revenue programs$64 $17 $8 $88 $46 $19 $23 
Other electric revenues(e)
Other electric revenues(e)
8 — — — — — — 
Other electric revenues(e)
16 — 3 — — — — 
Other natural gas revenues(e)
Other natural gas revenues(e)
— — 1 — — — — 
Total other revenuesTotal other revenues$62 $10 $18 $46 $26 $9 $11 Total other revenues$80 $17 $12 $88 $46 $19 $23 
Total revenues for reportable segmentsTotal revenues for reportable segments$1,535 $889 $974 $1,244 $553 $382 $310 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:
•$68 million, $6$11 million at ComEd
•$12 million, $1$3 million at PECO
•$23 million, $2$5 million at BGE
•$36 million, $3$7 million at PHI
•$12 million, $1$3 million at Pepco
•$23 million, $2$4 million at DPL
•$12 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, less than $1 million at PECO
•$67 million, $4$7 million at BGE
(e)Includes late payment charge revenues.

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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.
Three Months Ended June 30, 2022
ExelonComEdPECOBGEPHIPepcoDPLACE
Balance as of March 31, 2022Balance as of March 31, 2022$389 $92 $125 $59 $113 $40 $24 $49 
Plus: Current period (benefit) provision for expected credit lossesPlus: Current period (benefit) provision for expected credit losses(9)(5)(10)2 4 5 — (1)
Less: Write-offs, net of recoveries(a)
Less: Write-offs, net of recoveries(a)
26 6 8 4 8 3 2 3 
Balance as of June 30, 2022Balance as of June 30, 2022$354 $81 $107 $57 $109 $42 $22 $45 
Three Months Ended June 30, 2021
ExelonComEdPECOBGEPHIPepcoDPLACE
Balance as of March 31, 2021Balance as of March 31, 2021$377 $103 $130 $43 $101 $41 $25 $35 
Plus: Current period (benefit) provision for expected credit lossesPlus: Current period (benefit) provision for expected credit losses(42)(9)(14)(14)(5)(1)(5)1 
Less: Write-offs, net of recoveries(a)
Less: Write-offs, net of recoveries(a)
15 5 5 2 3 2 1 — 
Balance as of June 30, 2021Balance as of June 30, 2021$320 $89 $111 $27 $93 $38 $19 $36 
Three Months Ended March 31, 2022Six Months Ended June 30, 2022
ExelonComEdPECOBGEPHIPepcoDPLACEExelonComEdPECOBGEPHIPepcoDPLACE
Balance as of December 31, 2021Balance as of December 31, 2021$320 $73 $105 $38 $104 $37 $18 $49 Balance as of December 31, 2021$320 $73 $105 $38 $104 $37 $18 $49 
Plus: Current period provision for expected credit losses(a)(b)
Plus: Current period provision for expected credit losses(a)(b)
110 26 31 26 27 11 7 9 
Plus: Current period provision for expected credit losses(a)(b)
101 21 21 28 31 16 7 8 
Less: Write-offs, net of recoveries(b)(c)
41 7 11 5 18 8 1 9 
Balance as of March 31, 2022$389 $92 $125 $59 $113 $40 $24 $49 
Less: Write-offs, net of recoveries(a)(c)
Less: Write-offs, net of recoveries(a)(c)
67 13 19 9 26 11 3 12 
Balance as of June 30, 2022Balance as of June 30, 2022$354 $81 $107 $57 $109 $42 $22 $45 
Three Months Ended March 31, 2021Six Months Ended June 30, 2021
ExelonComEdPECOBGEPHIPepcoDPLACEExelonComEdPECOBGEPHIPepcoDPLACE
Balance as of December 31, 2020Balance as of December 31, 2020$334 $97 $116 $35 $86 $32 $22 $32 Balance as of December 31, 2020$334 $97 $116 $35 $86 $32 $22 $32 
Plus: Current period provision for expected credit losses(d)
70 21 20 9 20 11 6 3 
Less: Write-offs, net of recoveries(b)
27 15 6 1 5 2 3 — 
Balance as of March 31, 2021$377 $103 $130 $43 $101 $41 $25 $35 
Plus: Current period provision (benefit) for expected credit lossesPlus: Current period provision (benefit) for expected credit losses28 12 6 (5)15 10 1 4 
Less: Write-offs, net of recoveries(a)
Less: Write-offs, net of recoveries(a)
42 20 11 3 8 4 4 — 
Balance as of June 30, 2021Balance as of June 30, 2021$320 $89 $111 $27 $93 $38 $19 $36 
__________
(a)Recoveries were not material to the Registrants.
(b)For PECO, BGE, Pepco, and ACE, the increase is primarily as a result of increased receivable balances due to the increased aging of receivables. For BGE, also reflects increased receivable balance due to colder weather.
(b)Recoveries were not material to the Registrants.
(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.
(d)The increase is primarily as a result of increased receivable balances due to the colder weather and the increased aging of receivables, the temporary suspension of customer disconnections for non-payment, temporary cessation of new late payment fees, and reconnection of service for customers previously disconnected due to COVID-19.

The following tables present the rollforward of Allowance for Credit Losses on Other Accounts Receivable.
Three Months Ended March 31, 2022
ExelonComEdPECOBGEPHIPepcoDPLACE
Balance as of December 31, 2021$72 $17 $7 $9 $39 $16 $8 $15 
Plus: Current period provision for expected credit losses14 4 3 3 4 2 1 1 
Less: Write-offs, net of recoveries(a)
5 1 1 1 2 — — 2 
Balance as of March 31, 2022$81 $20 $9 $11 $41 $18 $9 $14 
Three Months Ended March 31, 2021
ExelonComEdPECOBGEPHIPepcoDPLACE
Balance as of December 31, 2020$71 $21 $8 $9 $33 $13 $9 $11 
Plus: Current period provision for expected credit losses10 1 4 1 4 2 1 1 
Less: Write-offs, net of recoveries(a)
2 — 1 1 — — — — 
Balance as of March 31, 2021$79 $22 $11 $9 $37 $15 $10 $12 
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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.
Three Months Ended June 30, 2022
ExelonComEdPECOBGEPHIPepcoDPLACE
Balance as of March 31, 2022$81 $20 $9 $11 $41 $18 $9 $14 
Plus: Current period provision (benefit) for expected credit losses2 (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 
Three Months Ended June 30, 2021
ExelonComEdPECOBGEPHIPepcoDPLACE
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 
Six Months Ended June 30, 2022
ExelonComEdPECOBGEPHIPepcoDPLACE
Balance as of December 31, 2021$72 $17 $7 $9 $39 $16 $8 $15 
Plus: Current period provision for expected credit losses15 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 
Six Months Ended June 30, 2021
ExelonComEdPECOBGEPHIPepcoDPLACE
Balance as of December 31, 2020$71 $21 $8 $9 $33 $13 $9 $11 
Plus: Current period provision (benefit) for expected credit losses5 (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 March 31,June 30, 2022 and December 31, 2021.
Unbilled customer revenues(a)
Unbilled customer revenues(a)
ExelonComEdPECOBGEPHIPepcoDPLACEExelonComEdPECOBGEPHIPepcoDPLACE
March 31, 2022$629 $189 $127 $139 $174 $89 $50 $35 
June 30, 2022June 30, 2022$636 $191 $138 $123 $184 $94 $41 $49 
December 31, 2021December 31, 2021747 240 161 171 175 82 53 40 December 31, 2021747 240 161 171 175 82 53 40 
__________
(a)Unbilled customer revenues are classified in Customer accounts receivables, net in the Registrants' Consolidated Balance Sheets.
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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 tables presenttable presents the total receivables purchased.
Total receivables purchased
Exelon(a)
ComEdPECO
BGE(a)
PHIPepcoDPLACE
Three months ended March 31, 2022$1,044 $248 $292 $222 $282 $174 $57 $51 
Three months ended March 31, 20211,023 266 290 199 268 166 56 46 
Total receivables purchased
Exelon(a)
ComEdPECO
BGE(a)
PHIPepcoDPLACE
Six months ended June 30, 2022$1,911 $456 $518 $391 $546 $342 $104 $100 
Six months ended June 30, 20211,838 485 507 343 503 310 103 90 
__________
(a)Includes $4 million of receivables purchased from Generation prior to the separation on February 1, 2022 for the six months ended June 30, 2022 and $12$15 million of receivables purchased from Generation for the threesix months ended March 31, 2022 and 2021, respectively.

June 30, 2021.
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Table of Contents
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)
ExelonComEd
PECO(b)
BGE(b)
PHI
Pepco(b)
DPL
ACE(b)
U.S. Federal statutory rate21.0 %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)
(5.4)7.9 (0.6)2.1 1.5 (3.4)7.2 6.7 
Plant basis differences(3.3)(0.5)(11.0)(1.3)(1.7)(2.4)(0.7)(1.0)
Excess deferred tax amortization(10.5)(5.5)(3.1)(19.0)(19.2)(15.7)(20.0)(24.5)
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(0.4)(0.3)— (1.5)(0.4)(0.4)(0.4)(0.4)
Other(d)
7.7 — — 1.4 (0.1)(0.5)1.8 (1.6)
Effective income tax rate9.0 %22.5 %6.3 %2.6 %1.0 %(1.4)%8.7 %— %
Three Months Ended June 30, 2021(a)
ExelonComEd
PECO(e)
BGE(e)
PHI
Pepco(e)
DPL
ACE(e)
U.S. Federal statutory rate21.0 %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 benefit1.1 8.0 (2.9)(12.5)2.4 (2.1)7.0 8.1 
Plant basis differences(4.0)(0.7)(12.5)(2.3)(1.1)(1.5)(0.7)(0.6)
Excess deferred tax amortization(13.4)(7.0)(3.3)(17.5)(22.3)(19.0)(21.9)(28.2)
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)
Effective income tax rate0.9 %19.3 %1.9 %(21.6)%(2.2)%(4.2)%3.2 %(2.8)%
Three Months Ended March 31, 2022(a)
ExelonComEd
PECO(b)
BGE(b)
PHI
Pepco(b)
DPL
ACE(b)
U.S. Federal statutory rate21.0 %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)
21.1 8.0 (0.1)2.4 3.7 (4.5)6.2 6.8 
Plant basis differences(3.6)(0.6)(11.3)(0.9)(1.6)(2.6)(0.7)(1.3)
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(0.1)(0.1)— (0.1)(0.1)— (0.2)(0.2)
Tax credits(d)
1.7 (0.3)— (0.4)(0.4)(0.4)(0.3)(0.3)
Other(e)
2.6 — — (0.1)0.2 (0.6)0.1 (0.1)
Effective income tax rate31.2 %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. 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 lower state income taxes, net of federal income tax benefit, is primarily related to a one-time impact associated with a state tax benefit of $43 million and indemnification adjustments pursuant to the Tax Matters Agreement of $5 million as a result of the separation.
(d)For Exelon, primarily related to indemnification adjustments pursuant to the Tax Matters Agreement of $48 million.
(e)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.
74

Three Months Ended March 31, 2021(a)
ExelonComEd
PECO(f)
BGE(f)
PHIPepcoDPL
ACE(f)
U.S. Federal statutory rate21.0 %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 benefit2.8 6.8 (1.6)(10.1)6.1 5.5 6.4 6.9 
Plant basis differences(3.4)(0.6)(10.5)(1.4)(1.5)(2.1)(0.7)(0.9)
Excess deferred tax amortization(12.0)(6.9)(3.2)(15.5)(19.3)(15.1)(18.5)(28.7)
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(0.3)(0.2)— (0.4)(0.2)(0.2)(0.1)(0.3)
Other(1.1)(3.5)(0.1)(0.1)(0.1)0.1 0.3 2.2 
Effective income tax rate6.9 %16.5 %5.6 %(6.6)%5.9 %9.2 %8.2 %— %


Table of Contents
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)
ExelonComEd
PECO(b)
BGE(b)
PHI
Pepco(b)
DPL
ACE(b)
U.S. Federal statutory rate21.0 %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 rate21.8 %22.3 %6.6 %4.1 %3.4 %(2.7)%7.2 %2.6 %

Six Months Ended June 30, 2021(a)
ExelonComEd
PECO(f)
BGE(f)
PHI
Pepco(f)
DPL
ACE(f)
U.S. Federal statutory rate21.0 %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 benefit2.0 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 rate4.7 %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 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 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 approximately $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.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.

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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 7 — Income Taxes
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.

Unrecognized Tax Benefits
Exelon, PHI and ACE have the following unrecognized tax benefits as of March 31,June 30, 2022 and December 31, 2021. ComEd's, PECO's, BGE's, Pepco's, and DPL's amounts are not material.
ExelonPHIACE
Exelon(a)
PHIACE
March 31, 2022$146 $56 $16 
June 30, 2022June 30, 2022$147 $58 $16 
December 31, 2021December 31, 2021143 56 16 December 31, 2021143 56 16 
__________
(a)As of March 31,June 30, 2022, Exelon recorded a receivable of approximately $50 million in Noncurrent 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 March 31,June 30, 2022, ACE has approximately $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 approximately $148 million primarily due to the long-term marginal state income tax rate change of approximately $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 approximately $17 million, and nondeductible transaction costs for federal and state taxes of approximately $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 of March 31, 2022,a result, Exelon recorded a receivable of approximately $55 million in Current other assets in the Consolidated Balance Sheet for Constellation’s share of taxes for periods prior to the separation.separation, as of March 31, 2022. As of June 30, 2022, the remaining amount of the receivable is $31 million.
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, Exelon recorded a payable of approximately $11 million and $484 million in Current other liabilities and Noncurrent other liabilities, respectively, in the Consolidated Balance Sheet for tax credit carryforwards that are expected to be utilized and reimbursed to Constellation. As of June 30, 2022, the current and noncurrent payable amounts are $0 million and $480 million, respectively.
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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 7 — Income Taxes
Long-Term Marginal State Income Tax Rate (All Registrants)
In the first quarter of 2022, Exelon updated its marginal state income tax rates for changes in state apportionment due to the separation, which resulted in an increase of approximately $67 million to the deferred tax liability at Exelon, and a corresponding adjustment to income 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 income 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 that are expected to be settled through future customer rates and an increase to income tax expense of $38 million (net of federal taxes). The tax rate decrease is not expected to have a material ongoing impact to Exelon’s and PECO’s financial statements.
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.
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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 March 31,June 30, 2022:
Operating Company(a)
Name of Plan:ComEd PECO BGE PHIPepcoDPLACE
Qualified Pension Plans:
Exelon Corporation Retirement ProgramXXXXXXX
Exelon Corporation Pension Plan for Bargaining Unit EmployeesX  
Exelon Pension PlanXXXXXXX
Pepco Holdings LLC Retirement PlanXXXXXXX
Non-Qualified Pension Plans:
Exelon Corporation Supplemental Pension Benefit Plan and 2000 Excess Benefit PlanX  X  X
Exelon Corporation Supplemental Management Retirement PlanX  X  XXX
Constellation Energy Group, Inc. Senior Executive Supplemental PlanX  X
Constellation Energy Group, Inc. Supplemental Pension PlanX  X
Constellation Energy Group, Inc. Benefits Restoration PlanXX  X
Baltimore Gas & Electric Company Executive Benefit PlanX  
Baltimore Gas & Electric Company Manager Benefit PlanXX  
Pepco Holdings LLC 2011 Supplemental Executive Retirement PlanXXXX
Conectiv Supplemental Executive Retirement PlanXXX
Pepco Holdings LLC Combined Executive Retirement PlanXX
Atlantic City Electric Director Retirement PlanXX
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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 PHIPepcoDPLACE
OPEB Plans:
PECO Energy Company Retiree Medical Plan  XX  XXXXX
Exelon Corporation Health Care ProgramXXXXXXX
Exelon Corporation Employees’ Life Insurance Plan  X  X  X
Exelon Corporation Health Reimbursement Arrangement Plan  X  X  X
BGE Retiree Medical PlanXXXXXX
BGE Retiree Dental PlanX
Exelon Employee Life Insurance Plan and Family Life Insurance PlanXXXXX
Exelon Retiree Medical Plan of Constellation Energy Nuclear Group, LLCXXX
Exelon Retiree Dental Plan of Constellation Energy Nuclear Group, LLCXXX
Pepco Holdings LLC Welfare Plan for RetireesXXXXXXX
__________
(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 2022 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%. The majority of the 2022 OPEB cost is calculated using an expected long-term rate of return on plan assets of 6.44% for funded plans and a discount rate of 3.20%.
During the first quarter of 2022, Exelon received an updated valuation of its pension and OPEB to reflect actual census data as of February 1, 2022. This valuation resulted in a decrease to the pension obligation of $24 million and an increase to the OPEB obligation of $5 million. Additionally, accumulated other comprehensive loss increased by $5 million (after-tax) and regulatory assets and liabilities decreased by $30 million and $3 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 March 31,June 30, 2022 and 2021.

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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 8 — Retirement Benefits
Pension BenefitsOPEB
Three Months Ended June 30,Three Months Ended June 30,
2022202120222021
Components of net periodic benefit cost:Components of net periodic benefit cost:
Service costService cost$58 $75 $10 $13 
Interest costInterest cost110 101 19 17 
Expected return on assetsExpected return on assets(205)(210)(25)(25)
Amortization of:Amortization of:
Prior service cost (credit)Prior service cost (credit)1 — (5)(7)
Actuarial lossActuarial loss73 99 4 8 
Net periodic benefit costNet periodic benefit cost$37 $65 $3 $6 
Pension BenefitsOPEBPension BenefitsOPEB
Three Months Ended March 31,Three Months Ended March 31,Six Months Ended June 30,Six Months Ended June 30,
20222021202220212022202120222021
Components of net periodic benefit cost:Components of net periodic benefit cost:Components of net periodic benefit cost:
Service costService cost$61 $74 $10 $14 Service cost$119 $148 $20 $26 
Interest costInterest cost110 102 19 17 Interest cost220 202 38 35 
Expected return on assetsExpected return on assets(209)(213)(25)(26)Expected return on assets(414)(421)(50)(50)
Amortization of:Amortization of:Amortization of:
Prior service cost (credit)Prior service cost (credit)1 1 (5)(6)Prior service cost (credit)2 1 (10)(13)
Actuarial lossActuarial loss76 100 4 7 Actuarial loss149 199 8 14 
Curtailment benefitsCurtailment benefits— — — (1)Curtailment benefits— — — (1)
Net periodic benefit costNet periodic benefit cost$39 $64 $3 $5 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, 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.
 Three Months Ended March 31,
Pension and OPEB Costs20222021
Exelon$42 $69 
ComEd16 32 
PECO(2)2 
BGE11 15 
PHI13 12 
Pepco2 2 
DPL1 1 
ACE3 3 
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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,
Pension and OPEB Costs (Benefit)2022202120222021
Exelon$40 $71 $82 $140 
ComEd14 32 30 64 
PECO(2)2 (4)4 
BGE11 16 22 31 
PHI13 12 26 24 
Pepco2 2 4 3 
DPL1 1 2 1 
ACE3 3 6 5 
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 allow 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 plansplan for the three and six months ended March 31,June 30, 2022 and 2021, respectively.
Three Months Ended March 31,Three Months Ended June 30,Six Months Ended June 30,
Savings Plans Matching Contributions20222021
Savings Plan Matching ContributionsSavings Plan Matching Contributions2022202120222021
ExelonExelon$20 $20 Exelon$23 $23 $43 $43 
ComEdComEd8 8 ComEd10 10 18 18 
PECOPECO3 3 PECO3 3 6 6 
BGEBGE2 2 BGE3 2 5 4 
PHIPHI3 3 PHI4 4 7 7 
PepcoPepco1 1 Pepco1 1 2 2 
DPLDPL1 1 DPL1 1 2 2 
ACEACE— — ACE1 1 1 1 

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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 9 — Derivative Financial Instruments
9. Derivative Financial Instruments (All Registrants)
The Registrants use derivative instruments to manage commodity price risk related to ongoing business operations.
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. 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.
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 meet certain qualifications.
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 gas price volatility and have no direct earnings impact as the costs are fully recovered from customers through
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(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.

RegistrantCommodityAccounting TreatmentHedging Instrument
ComEdElectricityNPNSFixed 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.
PECOElectricityNPNSFixed price contracts for default supply requirements through full requirements contracts.
GasNPNSFixed price contracts to cover about 10% of planned natural gas purchases in support of projected firm sales.
BGEElectricityNPNSFixed price contracts for all SOS requirements through full requirements contracts.
GasNPNSFixed price contracts for between 10-20% of forecasted system supply requirements for flowing (i.e., non-storage) gas for the November through March period.
PepcoElectricityNPNSFixed price contracts for all SOS requirements through full requirements contracts.
DPLElectricityNPNSFixed price contracts for all SOS requirements through full requirements contracts.
GasNPNSFixed and index priced contracts through full requirements contracts.
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.
ACEElectricityNPNSFixed price contracts for all BGS requirements through full requirements contracts.
__________
(a)See Note 3 — Regulatory Matters of the 2021 Recast Form 10-K for additional information.
(b)The fair value of the DPL economic hedge is not material as of March 31,June 30, 2022 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 in Other current assets in Exelon’s and ComEd’s Consolidated Balance Sheets were $15 million and none as of June 30, 2022 and December 31, 2021, respectively.
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 March 31,June 30, 2022, the amount of cash collateral held with external counterparties by Exelon, ComEd, BGE, PHI, Pepco, DPL, and DPLACE was $192$781 million, $72$133 million, $86$194 million, $452 million, $87 million, $224 million, and $73$141 million, respectively, which is recorded in Other current liabilities in Exelon's, ComEd's, BGE's, PHI's, Pepco's, DPL's, and DPL'sACE's Consolidated Balance Sheets. The amounts for PECO, BGE, Pepco, and ACE were not material asamount of March 31, 2022. As of December 31, 2021, 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 material as of December 31, 2021.cash collateral received from external counterparties
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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 9 — Derivative Financial Instruments
increased as of June 30, 2022 due to rising energy prices. The amount for PECO was not material as of June 30, 2022. As of December 31, 2021, 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 material as of December 31, 2021.
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 March 31,June 30, 2022, 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 March 31,June 30, 2022, they could have been required to post collateral to their counterparties of $39$37 million, $62$75 million, and $16$15 million, respectively.
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 as of March 31,June 30, 2022 and December 31, 2021. PECO and ComEd had no commercial paper borrowings as of March 31,June 30, 2022 and December 31, 2021.
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 IssuerCommercial Paper IssuerMarch 31, 2022December 31, 2021March 31, 2022December 31, 2021Commercial Paper IssuerJune 30, 2022December 31, 2021June 30, 2022December 31, 2021
Exelon(a)
Exelon(a)
$250 $599 0.87 %0.35 %
Exelon(a)
$353 $599 1.86 %0.35 %
PECOPECO210 — 1.86 %— %
BGEBGE250 130 0.87 %0.37 %BGE— 130 — %0.37 %
PHI(b)
PHI(b)
— 469 — %0.35 %
PHI(b)
43 469 1.85 %0.35 %
PepcoPepco— 175 — %0.33 %Pepco43 175 1.85 %0.33 %
DPLDPL— 149 — %0.36 %DPL— 149 — %0.36 %
ACEACE— 145 — %0.35 %ACE— 145 — %0.35 %
__________
(a)Exelon Corporate had $100 million of outstanding commercial paper borrowings at June 30, 2022 and no outstanding commercial paper borrowings as of March 31, 2022 and December 31, 2021.
(b)Represents the consolidated amounts of Pepco, DPL, and ACE.

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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' each entered into a new 5-year revolving credit facility that replaced its existing syndicated revolving credit facility. The following table reflects the credit agreements:
BorrowerAggregate Bank CommitmentInterest Rate
Exelon Corporate900 SOFR plus 1.275 %
ComEd1,000 SOFR plus 1.000 %
PECO600 SOFR plus 0.900 %
BGE600 SOFR plus 0.900 %
Pepco300 SOFR plus 1.075 %
DPL300 SOFR plus 1.000 %
ACE300 SOFR plus 1.075 %
See Note 1715 — Debt and Credit Agreements of the Exelon 2021 Recast Form 10-K for additional information on the Registrants' credit facilities.
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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 10 — Debt and Credit Agreements
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, 2022 and will expire on March 16, 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 commencingwhich commenced on July 24, 2022. All indebtedness pursuant to the loan agreement is unsecured.
Long-Term Debt
Issuance of Long-Term Debt
















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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 10 — Debt and Credit Agreements
Long-Term Debt
Issuance of Long-Term Debt
During the threesix months ended March 31,June 30, 2022, the following long-term debt was issued:
CompanyCompanyTypeInterest RateMaturityAmountUse of ProceedsCompanyTypeInterest RateMaturityAmountUse of Proceeds
ExelonExelonSMBC Term Loan AgreementSOFR plus 0.65%July 21, 2023$300Fund a cash payment to Constellation and for general corporate purposes.ExelonSMBC Term Loan AgreementSOFR plus 0.65%July 21, 2023$300Fund a cash payment to Constellation and for general corporate purposes.
ExelonExelonU.S. Bank Term Loan AgreementSOFR plus 0.65%July 21, 2023300Fund a cash payment to Constellation and for general corporate purposes.ExelonU.S. Bank Term Loan AgreementSOFR plus 0.65%July 21, 2023300Fund a cash payment to Constellation and for general corporate purposes.
ExelonExelonPNC Term Loan AgreementSOFR plus 0.65%July 24, 2023250Fund a cash payment to Constellation and for general corporate purposes.ExelonPNC Term Loan AgreementSOFR plus 0.65%July 24, 2023250Fund a cash payment to Constellation and for general corporate purposes.
ExelonExelonNotes2.75%March 15, 2027650Repay existing indebtedness and for general corporate purposes.Exelon
Notes(b)
2.75%March 15, 2027650Repay existing indebtedness and for general corporate purposes.
ExelonExelonNotes3.35%March 15, 2032650Repay existing indebtedness and for general corporate purposes.Exelon
Notes(b)
3.35%March 15, 2032650Repay existing indebtedness and for general corporate purposes.
ExelonExelonNotes4.10%March 15, 2052700Repay existing indebtedness and for general corporate purposes.Exelon
Notes(b)
4.10%March 15, 2052700Repay existing indebtedness and for general corporate purposes.
ComEdComEdFirst Mortgage Bonds, Series 1323.15%March 15, 2032300Repay outstanding commercial paper obligations and to fund other general corporate purposes.ComEdFirst Mortgage Bonds, Series 1323.15%March 15, 2032300Repay outstanding commercial paper obligations and to fund other general corporate purposes.
ComEdComEdFirst Mortgage Bonds, Series 1333.85%March 15, 2052450Repay outstanding commercial paper obligations and to fund other general corporate purposes.ComEdFirst Mortgage Bonds, Series 1333.85%March 15, 2052450Repay outstanding commercial paper obligations and to fund other general corporate purposes.
PECOPECOFirst and Refunding Mortgage Bonds4.60%May 15, 2052350Refinance existing indebtedness and for general corporate purposes.
BGEBGENotes4.55%June 1, 2052500Repay outstanding commercial paper obligations, repay existing indebtedness, and for general corporate purposes.
Pepco(a)
Pepco(a)
First Mortgage Bonds3.97%March 24, 2052400Repay existing indebtedness and for general corporate purposes.
Pepco(a)
First Mortgage Bonds3.97%March 24, 2052400Repay existing indebtedness and for general corporate purposes.
DPLDPLFirst Mortgage Bonds3.06%February 15, 2052125Repay existing indebtedness and for general corporate purposes.DPLFirst Mortgage Bonds3.06%February 15, 2052125Repay existing indebtedness and for general corporate purposes.
ACEACEFirst Mortgage Bonds2.27%February 15, 203225Repay existing indebtedness and for general corporate purposes.ACEFirst Mortgage Bonds2.27%February 15, 203225Repay existing indebtedness and for general corporate purposes.
ACEACEFirst Mortgage Bonds3.06%February 15, 2052150Repay existing indebtedness and for general corporate purposes.ACEFirst Mortgage Bonds3.06%February 15, 2052150Repay existing indebtedness and for general corporate purposes.
__________
(a)On March 24, 2022, Pepco entered into a purchase agreement of First Mortgage Bonds of $225 million at 3.35% due on September 15, 2032. The closing date of the issuance is expected to occur in September 2022.
(b)In connection with the issuance and sale of the Notes, Exelon entered into a Registration Rights Agreement with the representatives of the initial purchasers of the Notes and other parties. Pursuant 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, 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.
Long-Term Debt to Affiliates
As of December 31, 2021, Exelon Corporate had $319 million recorded to intercompany notes receivable from Generation. See Note 1715 — Debt and Credit Agreements of the Exelon 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 March 31,June 30, 2022, the Registrants are in compliance with debt covenants.
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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 March 31,June 30, 2022 and December 31, 2021. The Registrants have no financial liabilities classified as Level 1.
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.
March 31, 2022December 31, 2021June 30, 2022December 31, 2021
Carrying AmountFair ValueCarrying AmountFair ValueCarrying AmountFair ValueCarrying AmountFair Value
Level 2Level 3TotalLevel 2Level 3TotalLevel 2Level 3TotalLevel 2Level 3Total
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)
ExelonExelon$37,162 $35,174 $2,645 $37,819 $32,902 $34,897 $2,217 $37,114 Exelon$36,294 $30,960 $2,315 $33,275 $32,902 $34,897 $2,217 $37,114 
ComEdComEd10,515 10,894 — 10,894 9,773 11,305 — 11,305 ComEd10,516 9,609 — 9,609 9,773 11,305 — 11,305 
PECOPECO4,198 4,244 50 4,294 4,197 4,740 50 4,790 PECO4,192 3,772 50 3,822 4,197 4,740 50 4,790 
BGEBGE3,961 3,969 — 3,969 3,961 4,406 — 4,406 BGE4,456 4,096 — 4,096 3,961 4,406 — 4,406 
PHIPHI8,233 5,453 2,595 8,048 7,547 5,970 2,167 8,137 PHI8,027 4,853 2,265 7,118 7,547 5,970 2,167 8,137 
PepcoPepco3,841 2,901 1,272 4,173 3,445 3,201 975 4,176 Pepco3,642 2,465 1,104 3,569 3,445 3,201 975 4,176 
DPLDPL1,935 1,300 592 1,892 1,810 1,426 552 1,978 DPL1,938 1,210 503 1,713 1,810 1,426 552 1,978 
ACEACE1,757 1,007 732 1,739 1,582 1,091 641 1,732 ACE1,757 954 658 1,612 1,582 1,091 641 1,732 
Long-Term Debt to Financing TrustsLong-Term Debt to Financing TrustsLong-Term Debt to Financing Trusts
ExelonExelon$390 $— $435 $435 $390 $— $470 $470 Exelon$390 $— $398 $398 $390 $— $470 $470 
ComEdComEd205 — 228 228 205 — 248 248 ComEd205 — 209 209 205 — 248 248 
PECOPECO184 — 207 207 184 — 222 222 PECO184 — 189 189 184 — 222 222 
__________
(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 1715 - Debt and Credit Agreements of the Exelon 2021 Recast Form 10-K for unamortized debt issuance costs, unamortized debt discount and premium, net, and purchase accounting fair value adjustments and Note 1110 - Leases of the Exelon 2021 Recast Form 10-K for finance lease liabilities.

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(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 March 31,June 30, 2022 and December 31, 2021:
Exelon
As of March 31, 2022As of December 31, 2021
Level 1Level 2Level 3TotalLevel 1Level 2Level 3Total
Assets
Cash equivalents(a)
$2,418 $— $— $2,418 $524 $— $— $524 
Rabbi trust investments
Cash equivalents65 — — 65 60 — — 60 
Mutual funds55 — — 55 60 — — 60 
Fixed income— 9 — 9 — 10 — 10 
Life insurance contracts— 63 37 100 — 61 37 98 
Rabbi trust investments subtotal120 72 37 229 120 71 37 228 
Total assets2,538 72 37 2,647 644 71 37 752 
Liabilities
Mark-to-market derivative liabilities— — (144)(144)— — (219)(219)
Deferred compensation obligation— (84)— (84)— (131)— (131)
Total liabilities— (84)(144)(228)— (131)(219)(350)
Total net assets (liabilities)$2,538 $(12)$(107)$2,419 $644 $(60)$(182)$402 

As of June 30, 2022As of December 31, 2021
Level 1Level 2Level 3TotalLevel 1Level 2Level 3Total
Assets
Cash equivalents(a)
$1,319 $— $— $1,319 $524 $— $— $524 
Rabbi trust investments
Cash equivalents63 — — 63 60 — — 60 
Mutual funds52 — — 52 60 — — 60 
Fixed income— 8 — 8 — 10 — 10 
Life insurance contracts— 59 38 97 — 61 37 98 
Rabbi trust investments subtotal115 67 38 220 120 71 37 228 
Mark-to-market derivative assets— — 15 15 — — — — 
Total assets1,434 67 53 1,554 644 71 37 752 
Liabilities
Mark-to-market derivative liabilities— — (103)(103)— — (219)(219)
Deferred compensation obligation— (73)— (73)— (131)— (131)
Total liabilities— (73)(103)(176)— (131)(219)(350)
Total net assets (liabilities)$1,434 $(6)$(50)$1,378 $644 $(60)$(182)$402 
__________    
(a)Exelon excludes cash of $470$177 million and $464 million as of March 31,June 30, 2022 and December 31, 2021, respectively, and restricted cash of $110$340 million and $49 million as of March 31,June 30, 2022 and December 31, 2021, respectively, and includes long-term restricted cash of $92$59 million and $44 million as of March 31,June 30, 2022 and December 31, 2021, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets.

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(Dollars in millions, except per share data, unless otherwise noted)

Note 11 — Fair Value of Financial Assets and Liabilities

ComEd, PECO, and BGE
ComEdPECOBGEComEdPECOBGE
As of March 31, 2022Level 1Level 2Level 3TotalLevel 1Level 2Level 3TotalLevel 1Level 2Level 3Total
As of June 30, 2022As of June 30, 2022Level 1Level 2Level 3TotalLevel 1Level 2Level 3TotalLevel 1Level 2Level 3Total
AssetsAssetsAssets
Cash equivalents(a)
Cash equivalents(a)
$537 $— $— $537 $9 $— $— $9 $— $— $— $— 
Cash equivalents(a)
$409 $— $— $409 $11 $— $— $11 $318 $— $— $318 
Rabbi trust investmentsRabbi trust investmentsRabbi trust investments
Cash equivalents— — — — 1 — — 1 — — — — 
Mutual fundsMutual funds— — — — 9 — — 9 7 — — 7 Mutual funds— — — — 9 — — 9 7 — — 7 
Life insurance contractsLife insurance contracts— — — — — 17 — 17 — — — — Life insurance contracts— — — — — 16 — 16 — — — — 
Rabbi trust investments subtotalRabbi trust investments subtotal— — — — 10 17 — 27 7 — — 7 Rabbi trust investments subtotal— — — — 9 16 — 25 7 — — 7 
Mark-to-market derivative assets(b)
Mark-to-market derivative assets(b)
— — 15 15 — — — — — — — — 
Total assetsTotal assets537 — — 537 19 17 — 36 7 — — 7 Total assets409 — 15 424 20 16 — 36 325 — — 325 
LiabilitiesLiabilitiesLiabilities
Mark-to-market derivative liabilities(b)
Mark-to-market derivative liabilities(b)
— — (144)(144)— — — — — — — — 
Mark-to-market derivative liabilities(b)
— — (103)(103)— — — — — — — — 
Deferred compensation obligationDeferred compensation obligation— (9)— (9)— (8)— (8)— (5)— (5)Deferred compensation obligation— (8)— (8)— (7)— (7)— (4)— (4)
Total liabilitiesTotal liabilities— (9)(144)(153)— (8)— (8)— (5)— (5)Total liabilities— (8)(103)(111)— (7)— (7)— (4)— (4)
Total net assets (liabilities)Total net assets (liabilities)$537 $(9)$(144)$384 $19 $9 $— $28 $7 $(5)$— $2 Total net assets (liabilities)$409 $(8)$(88)$313 $20 $9 $— $29 $325 $(4)$— $321 
ComEdPECOBGE
As of December 31, 2021Level 1Level 2Level 3TotalLevel 1Level 2Level 3TotalLevel 1Level 2Level 3Total
Assets
Cash equivalents(a)
$237 $— $— $237 $9 $— $— $9 $— $— $— $— 
Rabbi trust investments
Mutual funds— — — — 11 — — 11 14 — — 14 
Life insurance contracts— — — — — 16 — 16 — — — — 
Rabbi trust investments subtotal— — — — 11 16 — 27 14 — — 14 
Total assets237 — — 237 20 16 — 36 14 — — 14 
Liabilities
Mark-to-market derivative liabilities(b)
— — (219)(219)— — — — — — — — 
Deferred compensation obligation— (10)— (10)— (9)— (9)— (7)— (7)
Total liabilities— (10)(219)(229)— (9)— (9)— (7)— (7)
Total net assets (liabilities)$237 $(10)$(219)$8 $20 $7 $— $27 $14 $(7)$— $7 
__________
(a)ComEd excludes cash of $71$21 million and $105 million as of March 31,June 30, 2022 and December 31, 2021, respectively, and restricted cash of $73$133 million and $42 million as of March 31,June 30, 2022 and December 31, 2021, respectively, and includes long-term restricted cash of $92$59 million and $43 million as of March 31,June 30, 2022 and December 31, 2021, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. PECO excludes cash of $25$21 million and $35 million as of March 31,June 30, 2022 and December 31, 2021, respectively. BGE excludes cash of $41$36 million and $51 million as of March 31,June 30, 2022 and December 31, 2021, respectively, and restricted cash of $34$205 million and $4 million as of March 31,June 30, 2022 and December 31, 2021, respectively.
(b)The Level 3 balance consists of the current asset of $15 million and current and noncurrent liability of none and $144$103 million, respectively, as of March 31,June 30, 2022 and none, $18 million and $201 million, respectively, as of December 31, 2021 related to floating-to-fixed energy swap contracts with unaffiliated suppliers.

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(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 March 31, 2022As of December 31, 2021As of June 30, 2022As of December 31, 2021
PHIPHILevel 1Level 2Level 3TotalLevel 1Level 2Level 3TotalPHILevel 1Level 2Level 3TotalLevel 1Level 2Level 3Total
AssetsAssetsAssets
Cash equivalents(a)
Cash equivalents(a)
$599 $— $— $599 $110 $— $— $110 
Cash equivalents(a)
$557 $— $— $557 $110 $— $— $110 
Rabbi trust investmentsRabbi trust investmentsRabbi trust investments
Cash equivalentsCash equivalents61 — — 61 59 — — 59 Cash equivalents60 — — 60 59 — — 59 
Mutual fundsMutual funds12 — — 12 14 — — 14 Mutual funds11 — — 11 14 — — 14 
Fixed incomeFixed income— 9 — 9 — 10 — 10 Fixed income— 8 — 8 — 10 — 10 
Life insurance contractsLife insurance contracts— 24 36 60 — 27 35 62 Life insurance contracts— 22 37 59 — 27 35 62 
Rabbi trust investments subtotalRabbi trust investments subtotal73 33 36 142 73 37 35 145 Rabbi trust investments subtotal71 30��37 138 73 37 35 145 
Total assetsTotal assets672 33 36 741 183 37 35 255 Total assets628 30 37 695 183 37 35 255 
LiabilitiesLiabilitiesLiabilities
Deferred compensation obligationDeferred compensation obligation— (17)— (17)— (18)— (18)Deferred compensation obligation— (14)— (14)— (18)— (18)
Total liabilitiesTotal liabilities— (17)— (17)— (18)— (18)Total liabilities— (14)— (14)— (18)— (18)
Total net assetsTotal net assets$672 $16 $36 $724 $183 $19 $35 $237 Total net assets$628 $16 $37 $681 $183 $19 $35 $237 
PepcoDPLACEPepcoDPLACE
As of March 31, 2022Level 1Level 2Level 3TotalLevel 1Level 2Level 3TotalLevel 1Level 2Level 3Total
As of June 30, 2022As of June 30, 2022Level 1Level 2Level 3TotalLevel 1Level 2Level 3TotalLevel 1Level 2Level 3Total
AssetsAssetsAssets
Cash equivalents(a)
Cash equivalents(a)
$294 $— $— $294 $152 $— $— $152 $153 $— $— $153 
Cash equivalents(a)
$115 $— $— $115 $223 $— $— $223 $218 $— $— $218 
Rabbi trust investmentsRabbi trust investmentsRabbi trust investments
Cash equivalentsCash equivalents59 — — 59 — — — — — — — — Cash equivalents59 — — 59 — — — — — — — — 
Life insurance contractsLife insurance contracts— 24 36 60 — — — — — — — — Life insurance contracts— 22 37 59 — — — — — — — — 
Rabbi trust investments subtotalRabbi trust investments subtotal59 24 36 119 — — — — — — — — Rabbi trust investments subtotal59 22 37 118 — — — — — — — — 
Total assetsTotal assets353 24 36 413 152 — — 152 153 — — 153 Total assets174 22 37 233 223 — — 223 218 — — 218 
LiabilitiesLiabilitiesLiabilities
Deferred compensation obligationDeferred compensation obligation— (2)— (2)— — — — — — — — Deferred compensation obligation— (1)— (1)— — — — — — — — 
Total liabilitiesTotal liabilities— (2)— (2)— — — — — — — — Total liabilities— (1)— (1)— — — — — — — — 
Total net assetsTotal net assets$353 $22 $36 $411 $152 $— $— $152 $153 $— $— $153 Total net assets$174 $21 $37 $232 $223 $— $— $223 $218 $— $— $218 
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Note 11 — Fair Value of Financial Assets and Liabilities
PepcoDPLACE
As of December 31, 2021Level 1Level 2Level 3TotalLevel 1Level 2Level 3TotalLevel 1Level 2Level 3Total
Assets
Cash equivalents(a)
$31 $— $— $31 $43 $— $— $43 $— $— $— $— 
Rabbi trust investments
Cash equivalents58 — — 58 — — — — — — — — 
Life insurance contracts— 27 35 62 — — — — — — — — 
Rabbi trust investments subtotal58 27 35 120 — — — — — — — — 
Total assets89 27 35 151 43 — — 43 — — — — 
Liabilities
Deferred compensation obligation— (2)— (2)— — — — — — — — 
Total liabilities— (2)— (2)— — — — — — — — 
Total net assets$89 $25 $35 $149 $43 $— $— $43 $— $— $— $— 
__________
(a)PHI excludes cash of $300$60 million and $100 million as of March 31,June 30, 2022 and December 31, 2021, respectively, and restricted cash of $2 million and $3 million as of both March 31,June 30, 2022 and December 31, 2021.2021, respectively. Pepco excludes cash of $239$14 million and $34 million as of March 31,June 30, 2022 and December 31, 2021, respectively, and restricted cash of $2 million and $3 million as of both March 31,June 30, 2022 and December 31, 2021.2021, respectively. DPL excludes cash of $41$26 million and $28 million as of March 31,June 30, 2022 and December 31, 2021, respectively. ACE excludes cash of $15 million and $29 million as of March 31,June 30, 2022 and December 31, 2021, respectively.
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(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 March 31,June 30, 2022 and 2021:
ExelonComEdPHI and Pepco
Three Months Ended June 30, 2022TotalMark-to-Market
Derivatives		Life Insurance Contracts
Balance as of April 1, 2022$(107)$(144)$36 
Total realized / unrealized gains
Included in net income(a)
1 — 1 
Included in regulatory assets/liabilities56 56 (b)— 
Balance at June 30, 2022$(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 $— $1 
ExelonComEdPHI and Pepco
Three months ended March 31, 2022TotalMark-to-Market
Derivatives		Life Insurance Contracts
Balance as of January 1, 2022$(182)$(219)$35 
Total realized / unrealized gains
Included in net income(a)
1 — 1 
Included in regulatory assets75 75 (b)— 
Transfers out of Level 3(1)— — 
Balance as of March 31, 2022$(107)$(144)$36 
The amount of total gains included in income attributed to the change in unrealized gains related to assets and liabilities as of March 31, 2022$1 $— $1 
90

ExelonComEdPHI and Pepco
Three Months Ended March 31, 2021TotalMark-to-Market
Derivatives		Life Insurance Contracts
Balance as of January 1, 2021$(267)$(301)$34 
Total realized / unrealized gains
Included in net income(a)
1 — 1 
Included in regulatory assets6 6 (b)— 
Balance as of March 31, 2021$(260)$(295)$35 
The amount of total gains included in income attributed to the change in unrealized gain related to assets and liabilities as of March 31, 2021$1 $— $1 


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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
ExelonComEdPHI and Pepco
Three Months Ended June 30, 2021TotalMark-to-Market
Derivatives		Life Insurance Contracts
Balance as of April 1, 2021$(260)$(295)$35 
Total realized / unrealized gains
Included in net income(a)
1 — 1 
Included in regulatory assets30 30 (b)— 
Purchases, sales, and settlements
Settlements(2)— (2)
Balance as of June 30, 2021$(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 $— $1 
ExelonComEdPHI and Pepco
Six months ended June 30, 2022TotalMark-to-Market
Derivatives		Life Insurance Contracts
Balance as of January 1, 2022$(182)$(219)$35 
Total realized / unrealized gains
Included in net income(a)
2 — 2 
Included in regulatory assets/liabilities131 131 (b)— 
Transfers out of Level 3(1)— — 
Balance as of June 30, 2022$(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 

ExelonComEdPHI and Pepco
Six Months Ended June 30, 2021TotalMark-to-Market
Derivatives		Life Insurance Contracts
Balance as of January 1, 2021$(267)$(301)$34 
Total realized / unrealized gains
Included in net income(a)
2 — 2 
Included in regulatory assets36 36 (b)— 
Purchases, sales, and settlements
Settlements(2)— (2)
Balance as of June 30, 2021$(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 
__________
(a)Classified in Operating and maintenance expense in the Consolidated Statements of Operations and Comprehensive Income.
(b)Includes $69$59 million of increases in fair value and an increasea decrease for realized lossesgains due to settlements of $6$3 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended March 31,June 30, 2022. Includes $2$25 million of decreasesincreases in fair value and an increase for realized losses due to settlements of $8$5 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended March 31,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, 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 and current and noncurrent liability of none and $103 million, respectively, as of June 30, 2022.

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(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 1816 — Fair Value of Financial Assets and Liabilities of the Exelon 2021 Recast Form 10-K.
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(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 tradeType of tradeFair Value as of March 31, 2022Fair Value as of December 31, 2021Valuation
Technique		Unobservable
Input		2022 Range & Arithmetic Average2021 Range & Arithmetic AverageType of tradeFair Value as of June 30, 2022Fair Value as of December 31, 2021Valuation
Technique		Unobservable
Input		2022 Range & Arithmetic Average2021 Range & Arithmetic Average
Mark-to-market derivativesMark-to-market derivatives$(144)$(219)Discounted
Cash Flow
Forward heat
rate(a)
8.90x-9.10x9.00x9x-10x9.13xMark-to-market derivatives$(88)$(219)Discounted
Cash Flow
Forward power price(a)
$30.54-$89.78$46.33$28.65-$47.10$33.96
Marketability
reserve		4%-5%4.35%3%-7%4.77%
Renewable
factor		92%-120%98%92%-120%97%
__________________
(a)Quoted forward natural gas rates are utilized to project the forward power curve for the delivery of energy at specified future dates.
The inputs listed above, which are as of the balance sheet date, would have a direct impact on the fair value of the above instruments if they were adjusted. An increase to the marketability reserves would decrease the fair value. An increase to the forward heat rate or renewable factorpower price would increase the fair value accordingly.value.

12. Commitments and Contingencies (All Registrants)
The following is an update to the current status of commitments and contingencies set forth in Note 1917 — Commitments and Contingencies of the Exelon 2021 Recast 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 March 31,June 30, 2022:
DescriptionDescriptionExelonPHIPepcoDPLACEDescriptionExelonPHIPepcoDPLACE
Total commitmentsTotal commitments$513 $320 $120 $89 $111 Total commitments$513 $320 $120 $89 $111 
Remaining commitments(a)
Remaining commitments(a)
65 55 46 6 3 
Remaining commitments(a)
61 53 44 6 3 
__________
(a)Remaining commitments extend through 2026 and include rate credits, energy efficiency programs and delivery system modernization.
In addition, Exelon has committed to purchase 100 MWs of wind energy in PJM. DPL has committed to conducting three RFPs to procure up to a total of 120 MWs of wind RECs for the purpose of meeting Delaware's renewable portfolio standards. DPL has conducted two of the three wind REC RFPs. The first 40 MW wind REC tranche was conducted in 2017 and did not result in a purchase agreement. The second 40 MW wind REC tranche was conducted in 2018 and resulted in a proposed REC purchase agreement that 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 conductedevaluated in the second halfthird quarter of 2022, with a potential award in the fourth quarter of 2022.

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Note 12 — Commitments and Contingencies
Commercial Commitments (All Registrants). The Registrants’ commercial commitments as of March 31,June 30, 2022, representing commitments potentially triggered by future events were as follows:
Expiration withinExpiration within
Total202220232024202520262027 and beyondTotal202220232024202520262027 and beyond
ExelonExelonExelon
Letters of creditLetters of credit$14 $12 $2 $— $— $— $— Letters of credit$17 $8 $9 $— $— $— $— 
Surety bonds(a)
Surety bonds(a)
201 188 11 2 — — — 
Surety bonds(a)
185 144 39 2 — — — 
Financing trust guaranteesFinancing trust guarantees378 — — — — — 378 Financing trust guarantees378 — — — — — 378 
Guaranteed lease residual values(b)
Guaranteed lease residual values(b)
30 1 3 6 5 5 10 
Guaranteed lease residual values(b)
30 — 2 6 6 5 11 
Total commercial commitmentsTotal commercial commitments$623 $201 $16 $8 $5 $5 $388 Total commercial commitments$610 $152 $50 $8 $6 $5 $389 
ComEdComEdComEd
Letters of creditLetters of credit$7 $7 $— $— $— $— $— Letters of credit$10 $4 $6 $— $— $— $— 
Surety bonds(a)
Surety bonds(a)
17 12 3 2 — — — 
Surety bonds(a)
16 9 5 2 — — — 
Financing trust guaranteesFinancing trust guarantees200 — — — — — 200 Financing trust guarantees200 — — — — — 200 
Total commercial commitmentsTotal commercial commitments$224 $19 $3 $2 $— $— $200 Total commercial commitments$226 $13 $11 $2 $— $— $200 
PECOPECOPECO
Letters of creditLetters of credit$1 $1 $— $— $— $— $— Letters of credit$1 $— $1 $— $— $— $— 
Surety bonds(a)
Surety bonds(a)
3 2 1 — — — — 
Surety bonds(a)
3 1 2 — — — — 
Financing trust guaranteesFinancing trust guarantees178 — — — — — 178 Financing trust guarantees178 — — — — — 178 
Total commercial commitmentsTotal commercial commitments$182 $3 $1 $— $— $— $178 Total commercial commitments$182 $1 $3 $— $— $— $178 
BGEBGEBGE
Letters of creditLetters of credit$2 $2 $— $— $— $— $— Letters of credit$2 $2 $— $— $— $— $— 
Surety bonds(a)
Surety bonds(a)
4 3 1 — — — — 
Surety bonds(a)
2 1 1 — — — — 
Total commercial commitmentsTotal commercial commitments$6 $5 $1 $— $— $— $— Total commercial commitments$4 $3 $1 $— $— $— $— 
PHIPHIPHI
Surety bonds(a)
Surety bonds(a)
$94 $91 $3 $— $— $— $— 
Surety bonds(a)
$95 $76 $19 $— $— $— $— 
Guaranteed lease residual values(b)
Guaranteed lease residual values(b)
30 1 3 6 5 5 10 
Guaranteed lease residual values(b)
30 — 2 6 6 5 11 
Total commercial commitmentsTotal commercial commitments$124 $92 $6 $6 $5 $5 $10 Total commercial commitments$125 $76 $21 $6 $6 $5 $11 
PepcoPepcoPepco
Surety bonds(a)
Surety bonds(a)
$84 $84 $— $— $— $— $— 
Surety bonds(a)
$84 $71 $13 $— $— $— $— 
Guaranteed lease residual values(b)
Guaranteed lease residual values(b)
10 — 1 2 2 2 3 
Guaranteed lease residual values(b)
10 — 1 2 2 2 3 
Total commercial commitmentsTotal commercial commitments$94 $84 $1 $2 $2 $2 $3 Total commercial commitments$94 $71 $14 $2 $2 $2 $3 
DPLDPLDPL
Surety bonds(a)
Surety bonds(a)
$6 $3 $3 $— $— $— $— 
Surety bonds(a)
$7 $3 $4 $— $— $— $— 
Guaranteed lease residual values(b)
Guaranteed lease residual values(b)
13 1 1 3 2 2 4 
Guaranteed lease residual values(b)
13 — — 3 3 2 5 
Total commercial commitmentsTotal commercial commitments$19 $4 $4 $3 $2 $2 $4 Total commercial commitments$20 $3 $4 $3 $3 $2 $5 
ACEACEACE
Surety bonds(a)
Surety bonds(a)
$4 $4 $— $— $— $— $— 
Surety bonds(a)
$4 $2 $2 $— $— $— $— 
Guaranteed lease residual values(b)
Guaranteed lease residual values(b)
7 — 1 1 1 1 3 
Guaranteed lease residual values(b)
7 — 1 1 1 1 3 
Total commercial commitmentsTotal commercial commitments$11 $4 $1 $1 $1 $1 $3 Total commercial commitments$11 $2 $3 $1 $1 $1 $3 
__________
(a)Surety bonds — Guarantees issued related to contract and commercial agreements, excluding bid bonds.
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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 8 years. The maximum potential obligation at the end of the minimum lease term would be $73$74 million guaranteed by Exelon and PHI, of which $25$24 million, $30$31 million, and $18$19 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 Federalfederal 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 these sites, there are additional PRPs that may share responsibility for the ultimate remediation of each location.
•ComEd has 21 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.
•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.
•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.
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Note 12 — Commitments and Contingencies
As of March 31,June 30, 2022 and December 31, 2021, 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:
March 31, 2022December 31, 2021June 30, 2022December 31, 2021
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
ExelonExelon$354 $305 $352 $303 Exelon$347 $299 $352 $303 
ComEdComEd279 279 279 279 ComEd274 273 279 279 
PECOPECO21 20 22 20 PECO21 20 22 20 
BGEBGE7 6 6 4 BGE7 6 6 4 
PHIPHI42 — 42 — PHI42 — 42 — 
PepcoPepco40 — 40 — Pepco40 — 40 — 
DPLDPL1 — 1 — DPL1 — 1 — 
ACEACE1 — 1 — ACE1 — 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 developing a FS to evaluate possible remedial alternatives for submission to DOEE. The Court has established a schedule for completion of the FS, and approval by the DOEE, by September 16, 2022. After completion and approval of the FS, 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. 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. In April 2018, DOEE released a draft RI report for public review and comment. Pepco submitted written comments to the draft RI and participated in a public hearing.
Exelon, PHI, and Pepco have determined that it is probable that costs for remediation will be incurred and recorded a liability in the third quarter 2019 for management’s best estimate of its share of those costs. 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
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Note 12 — Commitments and Contingencies
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 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) on behalf of DOEE conveying a settlement offer to resolve all PRPs' liability to the District. Pepco responded on July 27, 2022 to enter into settlement discussions. 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.
On July 12, 2021, DOEE and NPS held a virtual meeting with the PRP's in response to a General Notice Letter sent by each agency inviting the PRP's to participate in discussions, which Pepco attended.
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) 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") 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.
Litigation and Regulatory Matters
Deferred Prosecution Agreement (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 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 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 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
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Note 12 — Commitments and Contingencies
on October 22, 2020 which was granted on December 23, 2020. On December 2, 2020, the court 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 in the Seventh Circuit was filed on January 14, 2022. Exelon and ComEd filed their response brief on March 7, 2022, and plaintiffs filed their reply brief on April 6, 2022. The court has scheduled oralOral argument forwas held on May 17, 2022.
•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' opening appellate briefs are currently due June 3,August 5, 2022.
•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 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, the court granted an extension of the amendment to 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 May 15,September 30, 2022 and directedreset the parties to submit a proposed joint schedulenext court status for the additional case proceedings by May 13,August 15, 2022.
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Note 12 — Commitments and Contingencies
•Several shareholders have sent letters to the Exelon Board of Directors from 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”)(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. On January 31,February 3, 2022, the court granted an extension of the stay for another 120 days and directed the parties to file a status report on June 1, 2022. On June 1, 2022, the parties jointly movedrequested a further extension of the stay until September 14, 2022, which the court to extend the stay an additional 120 days.granted.
•Two separate shareholder requests seeking review of certain Exelon books and records were received in August 2021 and January 2022. Exelon responded to both requests and both shareholders have since sent formal shareholder demands to the Exelon Board, as discussed above.
No loss contingencies have been reflected in Exelon’s and ComEd’s consolidated financial statements with respect to these matters, as such contingencies are neither probable nor reasonably estimable at this time.
The ICC continues to conduct an investigation into rate impacts of conduct admitted in the DPA initiated on August 12, 2021. On December 16, 2021, ComEd filed direct testimony addressing the costs recovered from customers related to the DPA and Exelon's funding of the fine paid by ComEd. In that testimony, ComEd proposed to voluntarily refund to customers compensation costs 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 specifically identified in the DPA, as well as individuals and entities who were referred to ComEd as part of the conduct described in the DPA and who failed, during their tenure at ComEd, to perform work to management expectations. 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 outlined 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 proposed to increase its voluntary customer refund to $38 million, ofincluding ICC and FERC jurisdictional amounts and estimated interest, to resolve the issue of the potential expenditure of customer monies on activities identified in the DPA in this matter. An accrual for the amount of the voluntary customer refund has been recorded in Other current liabilities and Other deferred credits and other liabilities in Exelon’s and ComEd’s Consolidated Balance Sheets as of March 31,June 30, 2022. The voluntary 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”)(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. 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.
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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 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
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Note 12 — Commitments and Contingencies
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. Changes in Accumulated Other Comprehensive Income (Exelon)
The following tables present changes in Exelon's AOCI, net of tax, by component:
Three Months Ended March 31, 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)$(2,750)
Separation of Constellation6 1,994 23 2,023 
Three Months Ended June 30, 2022Three Months Ended June 30, 2022 Cash Flow Hedges
Pension and
Non-Pension
Postretirement
Benefit Plan
Items(a)
Foreign
Currency
Items		Total
Balance at March 31, 2022Balance at March 31, 2022$— $(713)$— $(713)
OCI before reclassificationsOCI before reclassifications— 2 — 2 
Amounts reclassified from AOCIAmounts reclassified from AOCI— 14 — 14 Amounts reclassified from AOCI— 10 — 10 
Net current-period OCINet current-period OCI— 14 — 14 Net current-period OCI— 12 — 12 
Balance at March 31, 2022$— $(713)$— $(713)
Balance at June 30, 2022Balance at June 30, 2022$— $(701)$— $(701)
Three Months Ended June 30, 2021Cash Flow Hedges
Pension and
Non-Pension
Postretirement
Benefit Plan
Items(a)
Foreign
Currency
Items		Total
Balance at March 31, 2021$(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)$(2,750)
Separation of Constellation6 1,994 23 2,023 
OCI before reclassifications— 2 — 2 
Amounts reclassified from AOCI— 24 — 24 
Net current-period OCI— 26 — 26 
Balance at June 30, 2022$— $(701)$— $(701)
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(Dollars in millions, except per share data, unless otherwise noted)

Note 13 — Changes in Accumulated Other Comprehensive Income
Three Months Ended March 31, 2021Losses on Cash Flow Hedges
Pension and
Non-Pension
Postretirement
Benefit Plan
Items(a)
Foreign
Currency
Items		Total
Six Months Ended June 30, 2021Six Months Ended June 30, 2021Cash Flow Hedges
Pension and
Non-Pension
Postretirement
Benefit Plan
Items(a)
Foreign
Currency
Items		Total
Balance at December 31, 2020Balance at December 31, 2020$(5)$(3,372)$(23)$(3,400)Balance at December 31, 2020$(5)$(3,372)$(23)$(3,400)
OCI before reclassificationsOCI before reclassifications— (2)1 (1)OCI before reclassifications— (2)3 1 
Amounts reclassified from AOCIAmounts reclassified from AOCI— 55 — 55 Amounts reclassified from AOCI— 110 — 110 
Net current-period OCINet current-period OCI— 53 1 54 Net current-period OCI— 108 3 111 
Balance at March 31, 2021$(5)$(3,319)$(22)$(3,346)
Balance at June 30, 2021Balance 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 March 31,Three Months Ended June 30,Six Months Ended June 30,
202220212022202120222021
Pension and non-pension postretirement benefit plans:Pension and non-pension postretirement benefit plans:Pension and non-pension postretirement benefit plans:
Prior service benefit reclassified to periodic benefit costPrior service benefit reclassified to periodic benefit cost$— $1 Prior service benefit reclassified to periodic benefit cost$— $1 $— $2 
Actuarial loss reclassified to periodic benefit costActuarial loss reclassified to periodic benefit cost(5)(19)Actuarial loss reclassified to periodic benefit cost(3)(19)(8)(38)
Pension and non-pension postretirement benefit plans valuation adjustmentPension 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:
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(Dollars in millions, except per share data, unless otherwise noted)

Note 14 — Supplemental Financial Information
Taxes other than income taxesTaxes other than income taxes
ExelonComEdPECOBGEPHIPepcoDPLACEExelonComEdPECOBGEPHIPepcoDPLACE
Three Months Ended March 31, 2022
Three Months Ended June 30, 2022Three Months Ended June 30, 2022
Utility taxes(a)
Utility taxes(a)
$221 $78 $38 $27 $78 $70 $7 $1 
Utility taxes(a)
$203 $71 $39 $20 $73 $67 $5 $1 
PropertyProperty94 10 4 46 34 23 10 1 Property94 10 4 46 33 23 10 — 
PayrollPayroll37 7 4 4 7 2 1 1 Payroll28 7 5 4 7 1 1 1 
Three Months Ended March 31, 2021
Three Months Ended June 30, 2021Three Months Ended June 30, 2021
Utility taxes(a)
Utility taxes(a)
$193 $59 $35 $25 $74 $67 $6 $1 
Utility taxes(a)
$184 $61 $32 $20 $71 $65 $5 $— 
PropertyProperty86 8 4 42 32 21 10 1 Property86 8 4 43 31 20 10 1 
PayrollPayroll33 7 4 5 7 2 1 — Payroll32 6 4 5 7 1 1 1 
Six Months Ended June 30, 2022Six Months Ended June 30, 2022
Utility taxes(a)
Utility taxes(a)
$424 $149 $77 $47 $151 $137 $12 $2 
PropertyProperty188 20 9 92 67 46 20 1 
PayrollPayroll64 13 8 9 14 3 2 2 
Six Months Ended June 30, 2021Six Months Ended June 30, 2021
Utility taxes(a)
Utility taxes(a)
$377 $121 $66 $45 $145 $132 $11 $1 
PropertyProperty173 16 9 85 63 42 19 1 
PayrollPayroll64 13 8 9 14 3 3 2 
_________
(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
ExelonComEdPECOBGE PHIPepcoDPLACE
Three Months Ended June 30, 2022
AFUDC — Equity$38 $9 $8 $6 $15 $11 $2 $2 
Non-service net periodic benefit cost16 — — — — — — — 
Three Months Ended June 30, 2021
AFUDC — Equity$34 $9 $6 $7 $12 $10 $1 $1 
Non-service net periodic benefit cost26 — — — — — — — 
Other, net
ExelonComEdPECOBGEPHIPepcoDPLACE
Three Months Ended March 31, 2022
AFUDC — Equity$36 $8 $7 $6 $15 $11 $2 $2 
Non-service net periodic benefit cost17 — — — — — — — 
Three Months Ended March 31, 2021
Six Months Ended June 30, 2022Six Months Ended June 30, 2022
AFUDC — EquityAFUDC — Equity$28 $4 $6 $7 $11 $9 $1 $1 AFUDC — Equity$74 $17 $15 $12 $30 $22 $4 $4 
Non-service net periodic benefit costNon-service net periodic benefit cost20 — — — — — — — Non-service net periodic benefit cost33 — — — — — — — 
Six Months Ended June 30, 2021Six Months Ended June 30, 2021
AFUDC — EquityAFUDC — Equity$64 $13 $12 $14 $25 $20 $3 $2 
Non-service net periodic benefit costNon-service net periodic benefit cost46 — — — — — — — 
Supplemental Cash Flow Information
The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Cash Flows.
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(Dollars in millions, except per share data, unless otherwise noted)

Note 14 — Supplemental Financial Information
Depreciation and amortizationDepreciation and amortization
Exelon(a)
ComEdPECOBGEPHIPepcoDPLACE
Exelon(a)
ComEdPECOBGEPHIPepcoDPLACE
Three Months Ended March 31, 2022
Six Months Ended June 30, 2022Six Months Ended June 30, 2022
Property, plant, and equipment(b)
Property, plant, and equipment(b)
$726 $254 $88 $117 $164 $72 $45 $41 
Property, plant, and equipment(b)
$1,376 $511 $177 $235 $335 $145 $92 $83 
Amortization of regulatory assets(b)
Amortization of regulatory assets(b)
179 67 4 54 54 36 12 6 
Amortization of regulatory assets(b)
357 138 8 87 124 68 21 35 
Amortization of intangible assets, net(b)
Amortization of intangible assets, net(b)
6 — — — — — — — 
Amortization of intangible assets, net(b)
8 — — — — — — — 
Amortization of energy contract assets and liabilities(c)
Amortization of energy contract assets and liabilities(c)
3 — — — — — — — 
Amortization of energy contract assets and liabilities(c)
3 — — — — — — — 
Nuclear fuel(d)
Nuclear fuel(d)
66 — — — — — — — 
Nuclear fuel(d)
66 — — — — — — — 
ARO accretion(e)
ARO accretion(e)
44 — — — — — — — 
ARO accretion(e)
44 — — — — — — — 
Total depreciation, amortization, and accretionTotal depreciation, amortization, and accretion$1,024 $321 $92 $171 $218 $108 $57 $47 Total depreciation, amortization, and accretion$1,854 $649 $185 $322 $459 $213 $113 $118 
Three Months Ended March 31, 2021
Six Months Ended June 30, 2021Six Months Ended June 30, 2021
Property, plant, and equipment(b)
Property, plant, and equipment(b)
$1,522 $239 $82 $106 $154 $67 $42 $37 
Property, plant, and equipment(b)
$3,043 $480 $165 $215 $309 $135 $84 $76 
Amortization of regulatory assets(b)
Amortization of regulatory assets(b)
160 53 4 46 56 35 11 10 
Amortization of regulatory assets(b)
291 109 8 78 95 64 20 11 
Amortization of intangible assets, net(b)
Amortization of intangible assets, net(b)
15 — — — — — — — 
Amortization of intangible assets, net(b)
29 — — — — — — — 
Amortization of energy contract assets and liabilities(c)
Amortization of energy contract assets and liabilities(c)
4 — — — — — — — 
Amortization of energy contract assets and liabilities(c)
13 — — — — — — — 
Nuclear fuel(d)
Nuclear fuel(d)
276 — — — — — — — 
Nuclear fuel(d)
549 — — — — — — — 
ARO accretion(e)
ARO accretion(e)
127 — — — — — — — 
ARO accretion(e)
255 — — — — — — — 
Total depreciation, amortization, and accretionTotal depreciation, amortization, and accretion$2,104 $292 $86 $152 $210 $102 $53 $47 Total depreciation, amortization, and accretion$4,180 $589 $173 $293 $404 $199 $104 $87 
__________
(a)Exelon's 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 Operating revenues or Purchased power and fuel expense in the Registrants’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.
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(Dollars in millions, except per share data, unless otherwise noted)

Note 14 — Supplemental Financial Information
Other non-cash operating activitiesOther non-cash operating activities
Exelon(a)
ComEdPECOBGEPHIPepcoDPLACE
Exelon(a)
ComEdPECOBGEPHIPepcoDPLACE
Three Months Ended March 31, 2022
Six Months Ended June 30, 2022Six Months Ended June 30, 2022
Pension and non-pension postretirement benefit costsPension and non-pension postretirement benefit costs$44 $16 $(2)$12 $13 $2 $1 $3 Pension and non-pension postretirement benefit costs$86 $30 $(4)$22 $26 $4 $2 $6 
Allowance for credit lossesAllowance for credit losses78 17 27 18 18 9 6 3 Allowance for credit losses96 29 21 18 29 16 6 7 
Other decommissioning-related activityOther decommissioning-related activity36 — — — — — — — Other decommissioning-related activity36 — — — — — — — 
Energy-related optionsEnergy-related options60 — — — — — — — Energy-related options60 — — — — — — — 
True-up adjustments to decoupling mechanisms and formula rates(b)
True-up adjustments to decoupling mechanisms and formula rates(b)
(29)(40)(6)12 5 7 1 (3)
True-up adjustments to decoupling mechanisms and formula rates(b)
(27)(75)(6)32 22 7 3 12 
Long-term incentive planLong-term incentive plan25 — — — — — — — Long-term incentive plan40 — — — — — — — 
Amortization of operating ROU assetAmortization of operating ROU asset23 1 — 7 7 2 2 1 Amortization of operating ROU asset38 1 — 14 14 4 4 2 
AFUDC — EquityAFUDC — Equity(36)(8)(7)(6)(15)(11)(2)(2)AFUDC — Equity(74)(17)(15)(12)(30)(22)(4)(4)
Three Months Ended March 31, 2021
Six Months Ended June 30, 2021Six Months Ended June 30, 2021
Pension and non-pension postretirement benefit costsPension and non-pension postretirement benefit costs$95 $32 $2 $14 $12 $2 $1 $3 Pension and non-pension postretirement benefit costs$196 $64 $4 $29 $24 $3 $1 $5 
Allowance for credit lossesAllowance for credit losses85 13 24 4 10 5 4 1 Allowance for credit losses100 24 17 4 9 5 2 2 
Other decommissioning-related activityOther decommissioning-related activity(322)— — — — — — — Other decommissioning-related activity(636)— — — — — — — 
Energy-related optionsEnergy-related options17 — — — — — — — Energy-related options20 — — — — — — — 
True-up adjustments to decoupling mechanisms and formula rates(b)
True-up adjustments to decoupling mechanisms and formula rates(b)
(129)(54)(10)(18)(46)(26)(9)(11)
True-up adjustments to decoupling mechanisms and formula rates(b)
(176)(64)(17)(8)(88)(46)(19)(23)
Long-term incentive planLong-term incentive plan32 — — — — — — — Long-term incentive plan62 — — — — — — — 
Amortization of operating ROU assetAmortization of operating ROU asset37 — — 7 7 1 3 1 Amortization of operating ROU asset83 1 — 15 14 3 5 2 
AFUDC — EquityAFUDC — Equity(28)(4)(6)(7)(11)(9)(1)(1)AFUDC — Equity(64)(13)(12)(14)(25)(20)(3)(2)
__________
(a)Exelon's 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 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 Exelon2021 Recast Form 10-K for additional information.

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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 14 — 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.
ExelonComEdPECOBGEPHIPepcoDPLACEExelonComEdPECOBGEPHIPepcoDPLACE
March 31, 2022
June 30, 2022June 30, 2022
Cash and cash equivalentsCash and cash equivalents$2,476 $343 $26 $41 $796 $502 $120 $168 Cash and cash equivalents$816 $120 $23 $354 $278 $14 $26 $233 
Restricted cash and cash equivalentsRestricted cash and cash equivalents430 246 8 34 106 34 73 — Restricted cash and cash equivalents961 384 9 205 341 117 223 — 
Restricted cash included in other long-term assetsRestricted cash included in other long-term assets92 92 — — — — — — Restricted cash included in other long-term assets59 59 — — — — — — 
Total cash, restricted cash, and cash equivalentsTotal cash, restricted cash, and cash equivalents$2,998 $681 $34 $75 $902 $536 $193 $168 Total cash, restricted cash, and cash equivalents$1,836 $563 $32 $559 $619 $131 $249 $233 
December 31, 2021December 31, 2021December 31, 2021
Cash and cash equivalentsCash and cash equivalents$672 $131 $36 $51 $136 $34 $28 $29 Cash and cash equivalents$672 $131 $36 $51 $136 $34 $28 $29 
Restricted cash and cash equivalentsRestricted cash and cash equivalents321 210 8 4 77 34 43 — Restricted cash and cash equivalents321 210 8 4 77 34 43 — 
Restricted cash included in other long-term assetsRestricted cash included in other long-term assets44 43 — — — — — — Restricted cash included in other long-term assets44 43 — — — — — — 
Cash, restricted cash, and cash equivalents from discontinued operationsCash, restricted cash, and cash equivalents from discontinued operations582— — — — — — — Cash, restricted cash, and cash equivalents from discontinued operations582— — — — — — — 
Total cash, restricted cash, and cash equivalentsTotal cash, restricted cash, and cash equivalents$1,619 $384 $44 $55 $213 $68 $71 $29 Total cash, restricted cash, and cash equivalents$1,619 $384 $44 $55 $213 $68 $71 $29 
March 31, 2021
June 30, 2021June 30, 2021
Cash and cash equivalentsCash and cash equivalents$1,908 $86 $48 $21 $558 $134 $64 $353 Cash and cash equivalents$1,578 $71 $376 $368 $61 $17 $17 $11 
Restricted cash and cash equivalentsRestricted cash and cash equivalents374 270 7 1 37 33 — 4 Restricted cash and cash equivalents379 240 8 3 42 33 5 3 
Restricted cash included in other long-term assetsRestricted cash included in other long-term assets52 43 — — 9 — — 9 Restricted cash included in other long-term assets52 43 — — 9 — — 9 
Total cash, restricted cash, and cash equivalents(a)
Total cash, restricted cash, and cash equivalents(a)
$2,334 $399 $55 $22 $604 $167 $64 $366 
Total cash, restricted cash, and cash equivalents(a)
$2,009 $354 $384 $371 $112 $50 $22 $23 
December 31, 2020December 31, 2020December 31, 2020
Cash and cash equivalentsCash and cash equivalents$663 $83 $19 $144 $111 $30 $15 $17 Cash and cash equivalents$432 $83 $19 $144 $111 $30 $15 $17 
Restricted cash and cash equivalentsRestricted cash and cash equivalents438 279 7 1 39 35 — 3 Restricted cash and cash equivalents349 279 7 1 39 35 — 3 
Restricted cash included in other long-term assetsRestricted cash included in other long-term assets53 43 — — 10 — — 10 Restricted cash included in other long-term assets53 43 — — 10 — — 10 
Cash, restricted cash, and cash equivalents - Held for Sale12 — — — — — — — 
Total cash, restricted cash, and cash equivalents(a)
$1,166 $405 $26 $145 $160 $65 $15 $30 
Cash, restricted cash, and cash equivalents from discontinued operationsCash, restricted cash, and cash equivalents from discontinued operations332 — — — — — — — 
Total cash, restricted cash, and cash equivalentsTotal 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.

For additional information on restricted cash see Note 1 — Significant Accounting Policies of the Exelon 2021 Recast Form 10-K.
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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 expensesAccrued expenses
ExelonComEdPECOBGEPHIPepcoDPLACEExelonComEdPECOBGEPHIPepcoDPLACE
March 31, 2022
June 30, 2022June 30, 2022
Compensation-related accruals(a)
Compensation-related accruals(a)
$370 $95 $51 $48 $73 $26 $15 $12 
Compensation-related accruals(a)
$428 $109 $57 $54 $82 $26 $16 $13 
Taxes accruedTaxes accrued258 95 15 78 94 85 10 9 Taxes accrued243 94 60 31 84 57 12 11 
Interest accruedInterest accrued346 66 36 39 77 37 21 17 Interest accrued331 124 40 44 59 31 9 14 
December 31, 2021December 31, 2021December 31, 2021
Compensation-related accruals(a)
Compensation-related accruals(a)
$596 $155 $77 $78 $113 $35 $20 $17 
Compensation-related accruals(a)
$596 $155 $77 $78 $113 $35 $20 $17 
Taxes accruedTaxes accrued253 94 14 53 96 88 9 11 Taxes accrued253 94 14 53 96 88 9 11 
Interest accruedInterest accrued297 116 41 44 52 28 8 11 Interest accrued297 116 41 44 52 28 8 11 
__________
(a)Primarily includes accrued payroll, bonuses and other incentives, vacation, and benefits.

15. 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 affiliates and an immaterial amount recorded as Operating and maintenance expense from affiliates at the Utility Registrants:
Three Months Ended March 31, Three Months Ended June 30,Six Months Ended June 30,
20222021 2022202120222021
ComEd(a)
ComEd(a)
$59 $85 
ComEd(a)
$— $78 $59 $163 
PECO(b)
PECO(b)
33 42 
PECO(b)
— 41 33 83 
BGE(c)
BGE(c)
18 72 
BGE(c)
— 58 18 130 
PHIPHI51 100 PHI— 77 51 176 
Pepco(d)
Pepco(d)
39 75 
Pepco(d)
— 55 39 130 
DPL(e)
DPL(e)
10 21 
DPL(e)
— 17 10 37 
ACE(f)
ACE(f)
2 4 
ACE(f)
— 5 2 9 
__________
(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.
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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 15 — 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 affiliatesCapitalized costsOperating and maintenance from affiliatesCapitalized costs
Three Months Ended March 31,Three Months Ended March 31,Three Months Ended June 30,Six Months Ended June 30,Three Months Ended June 30,Six Months Ended June 30,
202220212022202120222021202220212022202120222021
ExelonExelonExelon
BSC BSC$205 $114  BSC$139 $114 $344 $249 
PHISCO PHISCO19 17  PHISCO21 17 40 36 
ComEdComEdComEd
BSC BSC$85 $71 85 45  BSC$80 $72 $165 $143 67 45 152 102 
PECOPECOPECO
BSC BSC49 39 36 17  BSC47 40 96 80 20 17 56 44 
BGEBGEBGE
BSC BSC51 43 38 20  BSC51 45 102 88 22 20 60 43 
PHIPHIPHI
BSC BSC50 39 46 32  BSC46 37 96 76 30 32 76 60 
PHISCO PHISCO19 17  PHISCO— — — — 21 17 40 36 
PepcoPepcoPepco
BSC BSC29 22 17 13  BSC27 23 56 45 11 13 28 25 
PHISCO PHISCO29 30 8 7  PHISCO29 28 58 57 8 7 16 15 
DPLDPLDPL
BSC BSC18 14 14 10  BSC17 15 35 29 9 10 23 19 
PHISCO PHISCO24 25 6 5  PHISCO25 24 49 49 7 5 13 11 
ACEACEACE
BSC BSC15 12 15 8  BSC14 12 29 24 10 8 25 15 
PHISCO PHISCO21 22 5 5  PHISCO22 21 43 43 6 5 11 10 
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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 15 — Related Party Transactions

Current Receivables from/Payables to affiliates
The following tables present current receivables from affiliates and current payables to affiliates:
March 31,June 30, 2022
Receivables from affiliates:Receivables from affiliates:
Payables to affiliates:ComEdPECOBGEPepcoDPLACEBSCPHISCOOtherTotalPayables to affiliates:ComEdPECOBGEPepcoDPLACEBSCPHISCOOtherTotal
ComEdComEd$— $— $— $— $— $64 $— $2 $66 ComEd$— $— $— $— $— $57 $— $8 $65 
PECOPECO$— — — — — 33 — 5 38 PECO$— — — — — 25 — 4 29 
BGEBGE— — — — — 35 — 2 37 BGE— — — — — 28 — 2 30 
PHIPHI— — — — — — 7 1 10 18 PHI— — — — — — 5 — 10 15 
PepcoPepco— — — — — 19 15 — 34 Pepco— — — — 1 14 13 1 29 
DPLDPL— — — — — 3 12 — 15 DPL— — — 9 — 9 10 1 29 
ACEACE— — — — — 12 11 — 23 ACE— — — — — 9 10 1 20 
OtherOther3 — — — — — — — 3 Other3 — — — — — — — 3 
TotalTotal$3 $— $— $— $— $— $173 $39 $19 $234 Total$3 $— $— $9 $— $1 $147 $33 $27 $220 
December 31, 2021
Receivables from affiliates:Receivables from affiliates:
Payables to affiliates:ComEdPECOBGEPepcoDPLACEGenerationBSCPHISCOOtherTotalPayables to affiliates:ComEdPECOBGEPepcoDPLACEGenerationBSCPHISCOOtherTotal
ComEdComEd$— $— $— $— $— 41 $71 $— $9 $121 ComEd$— $— $— $— $— $41 $71 $— $9 $121 
PECOPECO$— — — — — 30 36 — 4 70 PECO$— — — — — 30 36 — 4 70 
BGEBGE— — — — — 4 41 — 3 48 BGE— — — — — 4 41 — 3 48 
PHIPHI— 1 — — — 1 — 5 — 9 16 PHI— 1 — — — 1 — 5 — 9 16 
PepcoPepco— — 1 1 1 20 21 12 3 59 Pepco— — 1 1 1 20 21 12 3 59 
DPLDPL— — — — — 4 17 11 1 33 DPL— — — — — 4 17 11 1 33 
ACEACE— — — — — 7 13 9 2 31 ACE— — — — — 7 13 9 2 31 
GenerationGeneration13 — — — — — 102 — 16 131 Generation13 — — — — — 102 — 16 131 
OtherOther3 — — — — — 11 — — 14 Other3 — — — — — 11 — — 14 
TotalTotal$16 $1 $1 $— $1 $2 $117 $306 $32 $47 $523 Total$16 $1 $1 $— $1 $2 $117 $306 $32 $47 $523 
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 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 March 31,June 30, 2022 and in noncurrent Receivables from affiliates as of December 31, 2021. See Note 103 — Asset Retirement ObligationsRegulatory Matters of the Combined Notes to Consolidated Financial Statements of the Exelon 2021 Recast Form 10-K for additional information.
Long-term debt to financing trusts
The following table presents Long-term debt to financing trusts:
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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)
(Dollars in millions, except per share data, unless otherwise noted)

Note 15 — Related Party Transactions

March 31, 2022December 31, 2021June 30, 2022December 31, 2021
ExelonComEdPECOExelonComEdPECOExelonComEdPECOExelonComEdPECO
ComEd Financing IIIComEd Financing III$206 $205 $— $206 $205 $— ComEd Financing III$206 $205 $— $206 $205 $— 
PECO Trust IIIPECO Trust III81 — 81 81 — 81 PECO Trust III81 — 81 81 — 81 
PECO Trust IVPECO Trust IV103 — 103 103 — 103 PECO Trust IV103 — 103 103 — 103 
TotalTotal$390 $205 $184 $390 $205 $184 Total$390 $205 $184 $390 $205 $184 

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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 distribution and transmission 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 March 31,June 30, 2022 compared to the same period in 2021. For additional information regarding the financial results for the three and six months ended March 31,June 30, 2022 and 2021 see the discussions of Results of Operations by Registrant.
Three Months Ended March 31,(Unfavorable) Favorable VarianceThree Months Ended June 30,Favorable (Unfavorable) VarianceSix Months Ended June 30,Favorable (Unfavorable) Variance
2022202120222021Favorable (Unfavorable) Variance20222021Favorable (Unfavorable) Variance
ExelonExelon$481 $525 $(44)Exelon$465 $326 $139 $946 $851 $95 
ComEdComEd188 197 (9)ComEd227 192 35 415 390 25 
PECOPECO206 167 39 PECO133 104 29 339 271 68 
BGEBGE198 209 (11)BGE37 45 (8)234 254 (20)
PHIPHI130 128 2 PHI100 141 (41)230 269 (39)
PepcoPepco46 59 (13)Pepco70 75 (5)116 134 (18)
DPLDPL56 56 — DPL21 30 (9)77 86 (9)
ACEACE26 14 12 ACE11 37 (26)37 51 (14)
Other(a)
Other(a)
(241)(176)(65)
Other(a)
(32)(156)124 (272)(333)61 
__________
(a)Primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities and other financing and investing 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.
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 March 31,June 30, 2022 Compared to Three Months Ended March 31,June 30, 2021. Net income attributable to common shareholders from continuing operations decreasedincreased by $44$139 million and diluted
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earnings per average common share from continuing operations decreasedincreased to $0.49$0.47 in 2022 from $0.53$0.33 in 2021 primarily due to:
•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, and nondeductible transaction costs;
•Higher depreciation expense at BGE and PHI; and
•Higher storm costs at PHI.
The decreases were partially offset by:
•Higher electric distribution earnings from higher rate base and higher allowed electric distribution ROE due to an increase in treasury rates and higher rate base at ComEd;

•The favorable impacts of regulatory 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.
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net income attributable to common shareholders from continuing operations increased by $95 million and diluted earnings per average common share from continuing operations increased to $0.96 in 2022 from $0.87 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;
•Lower BSC costs presented in Exelon’s continuing operations, which were previously allocated to Generation but do not qualify as expenses of the discontinued operation per the accounting rules. Such costs, on a pre-tax basis, were $28 million for the period in 2022 prior to the separation on February 1, 2022 (January 1, 2022 to January 31, 2022) and $106$206 million for the threesix months ended March 31,June 30, 2021.
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, and nondeductible transaction costs partially offset by a one-time impact associated with a state tax benefit;
•The absence of favorable weather and volume as a result of the CIP at ACE;
•Higher depreciation expense at PECO, BGE, and PHI;
•Higher credit loss expense at BGE and PHI;
•Higher storm costs at PHI; and
•Higher interest expense at PHI and Exelon Corporate.
Adjusted (non-GAAP) Operating Earnings. In addition to net 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
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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.
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The following table providestables provide a reconciliation between net income attributable to common shareholders from continuing operations as determined in accordance with GAAP and adjusted (non-GAAP) operating earnings for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021.
Three Months Ended June 30,
20222021
(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 
Three Months Ended March 31,
20222021
(In millions, except per share data)Earnings per
Diluted Share		Earnings per
Diluted Share
Net Income Attributable to Common Shareholders from Continuing Operations$481 $0.49 $525 $0.53 
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $1)— — (1)— 
COVID-19 Direct Costs (net of taxes of $1)(a)
— — 2 — 
Acquisition Related Costs (net of taxes of $2)(b)
— — 6 0.01 
ERP System Implementation Costs (net of taxes of $0 and $2, respectively)(c)
1 — 5 0.01 
Separation Costs (net of taxes of $7 and $1, respectively)(d)
17 0.02 5 0.01 
Income Tax-Related Adjustments (entire amount represents tax expense)(e)
134 0.14 — — 
Adjusted (non-GAAP) Operating Earnings$634 $0.64 $542 $0.55 
Six Months Ended June 30,
20222021
(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 
__________
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 2022 and 2021 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
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(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) system implementation, which are recorded in Operating and maintenance expense.
(d)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)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.costs partially offset by a one-time impact associated with a state tax benefit.

Significant 2022 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 meets 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.
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In connection with the separation, Exelon incurred separation costs impacting continuing operations of $24$14 million and $4$16 million on a pre-tax basis for the three months ended March 31,June 30, 2022 and March 31,2021, 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 2022 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. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information on these and other regulatory proceedings.information.
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Completed Distribution Base Rate Case Proceedings
Registrant/JurisdictionRegistrant/JurisdictionFiling DateServiceRequested Revenue Requirement IncreaseApproved Revenue Requirement IncreaseApproved ROEApproval DateRate Effective DateRegistrant/JurisdictionFiling DateServiceRequested Revenue Requirement IncreaseApproved Revenue Requirement IncreaseApproved ROEApproval DateRate Effective Date
ComEd - IllinoisComEd - IllinoisApril 16, 2021Electric$51 $46 7.36 %December 1, 2021January 1, 2022ComEd - IllinoisApril 16, 2021Electric$51 $46 7.36 %December 1, 2021January 1, 2022
PECO - PennsylvaniaPECO - PennsylvaniaMarch 30, 2021Electric246 132 N/ANovember 18, 2021January 1, 2022PECO - PennsylvaniaMarch 30, 2021Electric246 132 N/ANovember 18, 2021January 1, 2022
BGE - MarylandBGE - MarylandMay 15, 2020 (amended September 11, 2020)Electric203 140 9.50 %December 16, 2020January 1, 2021BGE - MarylandMay 15, 2020 (amended September 11, 2020)Electric203 140 9.50 %December 16, 2020January 1, 2021
Natural Gas108 74 9.65 %Natural Gas108 74 9.65 %
Pepco - District of ColumbiaPepco - District of ColumbiaMay 30, 2019 (amended June 1, 2020)Electric136 109 9.28 %June 8, 2021July 1, 2021Pepco - District of ColumbiaMay 30, 2019 (amended June 1, 2020)Electric136 109 9.275 %June 8, 2021July 1, 2021
Pepco - MarylandPepco - MarylandOctober 26, 2020 (amended March 31, 2021)Electric104 52 9.55 %June 28, 2021June 28, 2021Pepco - MarylandOctober 26, 2020 (amended March 31, 2021)Electric104 52 9.55 %June 28, 2021June 28, 2021
DPL - MarylandDPL - MarylandSeptember 1, 2021 (amended December 23, 2021)Electric27 13 9.60 %March 2, 2022March 2, 2022DPL - MarylandSeptember 1, 2021 (amended December 23, 2021)Electric27 13 9.60 %March 2, 2022March 2, 2022
ACE - New JerseyACE - New JerseyDecember 9, 2020 (amended February 26, 2021)Electric67 41 9.60 %July 14, 2021January 1, 2022ACE - New JerseyDecember 9, 2020 (amended February 26, 2021)Electric67 41 9.60 %July 14, 2021January 1, 2022
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Pending Distribution Base Rate Case Proceedings
Registrant/JurisdictionRegistrant/JurisdictionFiling DateServiceRequested Revenue Requirement IncreaseRequested ROEExpected Approval TimingRegistrant/JurisdictionFiling DateServiceRequested Revenue Requirement IncreaseRequested ROEExpected Approval Timing
ComEd - IllinoisComEd - IllinoisApril 15, 2022Electric$199 7.85 %Fourth quarter of 2022ComEd - IllinoisApril 15, 2022Electric$199 7.85 %Fourth quarter of 2022
PECO - PennsylvaniaPECO - PennsylvaniaMarch 31, 2022Natural Gas82 10.95 %Fourth quarter of 2022PECO - PennsylvaniaMarch 31, 2022Natural Gas82 10.95 %Fourth quarter of 2022
DPL - DelawareDPL - DelawareJanuary 14, 2022 (amended February 28, 2022)Natural Gas15 10.30 %First quarter of 2023DPL - DelawareJanuary 14, 2022 (amended February 28, 2022)Natural Gas15 10.30 %First quarter of 2023
DPL - MarylandDPL - MarylandMay 19, 2022Electric38 10.25 %Fourth quarter of 2022
Transmission Formula Rates
For 2022, the following total increasesincreases/(decreases) were included in ComEd’s and BGE'sthe Utility Registrants' electric transmission formula rate update.updates. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information on these and other regulatory proceedings.information.
RegistrantRegistrantInitial Revenue Requirement IncreaseAnnual Reconciliation DecreaseTotal Revenue Requirement IncreaseAllowed Return on Rate BaseAllowed ROERegistrantInitial Revenue Requirement IncreaseAnnual Reconciliation (Decrease) IncreaseTotal Revenue Requirement IncreaseAllowed Return on Rate BaseAllowed ROE
ComEdComEd$24 $(24)$— 8.11 %11.50 %ComEd$24 $(24)$— 8.11 %11.50 %
PECOPECO23 16 39 7.30 %10.35 %
BGEBGE25 (4)16 7.30 %10.50 %BGE25 (4)16 7.30 %10.50 %
PepcoPepco16 15 31 7.60 %10.50 %
DPLDPL9 2 11 7.09 %10.50 %
ACEACE21 13 34 7.18 %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% 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 0.5% 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 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. See Note 7 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information.
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Other Key Business Drivers and Management Strategies
The following discussion of other key business driverdrivers 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  andin the 2021 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 Registrants' combined 2021 Recast 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
Infrastructure Investment and Jobs Act
On November 15, 2021, President Biden signed the $1.2 trillion Infrastructure Investment and Jobs Act (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 analyzing 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 Act
On July 27, 2022, the Inflation Reduction Act was introduced in the U.S. Senate. The bill extends tax benefits for renewable technologies like solar and wind and it creates new tax benefits for alternative clean energy sources like nuclear and hydrogen and it focuses on energy efficiency, electrification, and equity. However, 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 and cannot predict the outcome of the proposed legislation.
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 March 31,June 30, 2022, the Registrants’ critical accounting policies and estimates had not changed significantly from December 31, 2021 except for critical accounting policies and estimates that relate to Generation, which are no longer applicable to the Registrants.2021. See ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS — Critical Accounting Policies and Estimates in the Registrants' 2021 Recast Form 10-K for further information.
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Results of Operations by Registrant
Results of Operations — ComEd
Three Months Ended
March 31,		Favorable
(Unfavorable)
Variance		Three Months Ended
June 30,		Favorable
(Unfavorable)
Variance		Six Months Ended
June 30,		Favorable
(Unfavorable)
Variance
2022202120222021Favorable
(Unfavorable)
Variance		20222021Favorable
(Unfavorable)
Variance
Operating revenuesOperating revenues$1,734 $1,535 $199 Operating revenues$1,425 $1,517 $(92)$3,158 $3,052 $106 
Operating expensesOperating expensesOperating expenses
Purchased powerPurchased power638 527 (111)Purchased power283 500 217 921 1,025 104 
Operating and maintenanceOperating and maintenance351 316 (35)Operating and maintenance338 323 (15)689 639 (50)
Depreciation and amortizationDepreciation and amortization321 292 (29)Depreciation and amortization328 296 (32)649 589 (60)
Taxes other than income taxesTaxes other than income taxes96 75 (21)Taxes other than income taxes90 77 (13)185 153 (32)
Total operating expensesTotal operating expenses1,406 1,210 (196)Total operating expenses1,039 1,196 157 2,444 2,406 (38)
Loss on sales of assetsLoss on sales of assets(2)— (2)(2)— (2)
Operating incomeOperating income328 325 3 Operating income384 321 63 712 646 66 
Other income and (deductions)Other income and (deductions)Other income and (deductions)
Interest expense, netInterest expense, net(100)(96)(4)Interest expense, net(104)(98)(6)(204)(193)(11)
Other, netOther, net12 7 5 Other, net13 15 (2)26 22 4 
Total other income and (deductions)Total other income and (deductions)(88)(89)1 Total other income and (deductions)(91)(83)(8)(178)(171)(7)
Income before income taxesIncome before income taxes240 236 4 Income before income taxes293 238 55 534 475 59 
Income taxesIncome taxes52 39 (13)Income taxes66 46 (20)119 85 (34)
Net incomeNet income$188 $197 $(9)Net income$227 $192 $35 $415 $390 $25 
Three Months Ended March 31,June 30, 2022 Compared to Three Months Ended March 31,June 30, 2021. Net income decreasedincreased by $9$35 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).
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 refund related to the ICC investigation of matters identified in the Deferred Prosecution Agreement, partially offset by increases in electric distribution formula rate earnings (reflecting the impacts of higher rate base and higher allowed electric distribution ROE due to an increase in treasury rates).Agreement. See Note 12 -— Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for additional information related to the Deferred Prosecution Agreement.information.
The changes in Operating revenues consisted of the following:
Three Months Ended
March 31, 2022
Increase
Distribution$45 
Transmission21 
Energy efficiency7 
Other3 
76 
Regulatory required programs123 
Total increase$199 
Three Months Ended
June 30, 2022		Six Months Ended
June 30, 2022
Increase (Decrease)Increase (Decrease)
Distribution$65 $110 
Transmission17 38 
Energy efficiency14 20 
Other— 3 
96 171 
Regulatory required programs(188)(65)
Total increase$(92)$106 
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.
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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 March 31,June 30, 2022 as compared to the
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ComEd
same period in 2021, due to the impact of higher rate base, higher allowed ROE due to an increase in 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 March 31,June 30, 2022 as compared to the same periodsperiod 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 March 31,June 30, 2022 as compared to the same period in 2021, 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 same for the three and six months ended March 31,June 30, 2022 as compared to the same period in 2021.
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"), 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 increasedecrease of $111$217 million and $104 million for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021, in Purchased power expense is offset in Operating revenues as part of regulatory required programs.
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The changes in Operating and maintenance expense consisted of the following:
Three Months Ended
March 31, 2022
Increase (Decrease)
Storm-related costs$1 
Pension and non-pension postretirement benefits expense(7)
Labor, other benefits, contracting and materials2 
BSC costs14 
Other(a)
21 
31 
Regulatory required programs(b)
4 
Total increase$35 
Three Months Ended
June 30, 2022		Six Months Ended
June 30, 2022
(Decrease) Increase(Decrease) Increase
Storm-related costs$(1)$— 
Pension and non-pension postretirement benefits expense(7)(14)
Labor, other benefits, contracting and materials9 11 
BSC costs9 22 
Other(a)
4 26 
14 45 
Regulatory required programs(b)
1 5 
Total increase$15 $50 
__________
(a)TheFor 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
March 31, 2022
Increase
Depreciation and amortization(a)
$15 
Regulatory asset amortization(b)
14 
Total increase$29 
Three Months Ended
June 30, 2022		Six Months Ended
June 30, 2022
IncreaseIncrease
Depreciation and amortization(a)
$19 $33 
Regulatory asset amortization(b)
13 27 
Total increase$32 $60 
__________
(a)Reflects ongoing capital expenditures.
(b)Includes amortization of ComEd's energy efficiency formula rate regulatory assetasset.
Taxes other than income taxes increased by $21$13 million and by $32 million for the three and six months ended March 31,June 30, 2022, respectively, compared to the same period in 2021, primarily due to taxes related to ETAC, which is recovered through Operating revenues.
Effective income tax rates were 21.7%22.5% and 16.5%19.3% for the three months ended March 31,June 30, 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.
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PECO
Results of Operations — PECO
Three Months Ended
March 31,		Favorable
(Unfavorable)
Variance		Three Months Ended
June 30,		Favorable
(Unfavorable)
Variance		Six Months Ended
June 30,		Favorable
(Unfavorable)
Variance
2022202120222021Favorable
(Unfavorable)
Variance		20222021Favorable
(Unfavorable)
Variance
Operating revenuesOperating revenues$1,047 $889 $158 Operating revenues$816 $693 $123 $1,863 $1,582 $281 
Operating expensesOperating expensesOperating expenses
Purchased power and fuelPurchased power and fuel407 316 (91)Purchased power and fuel283 207 (76)689 523 (166)
Operating and maintenanceOperating and maintenance247 234 (13)Operating and maintenance215 209 (6)463 443 (20)
Depreciation and amortizationDepreciation and amortization92 86 (6)Depreciation and amortization93 87 (6)185 173 (12)
Taxes other than income taxesTaxes other than income taxes47 43 (4)Taxes other than income taxes48 49 1 95 92 (3)
Total operating expensesTotal operating expenses793 679 (114)Total operating expenses639 552 (87)1,432 1,231 (201)
Operating incomeOperating income254 210 44 Operating income177 141 36 431 351 80 
Other income and (deductions)Other income and (deductions)Other income and (deductions)
Interest expense, netInterest expense, net(41)(38)(3)Interest expense, net(43)(42)(1)(84)(80)(4)
Other, netOther, net7 5 2 Other, net8 7 1 16 12 4 
Total other income and (deductions)Total other income and (deductions)(34)(33)(1)Total other income and (deductions)(35)(35)— (68)(68)— 
Income before income taxesIncome before income taxes220 177 43 Income before income taxes142 106 36 363 283 80 
Income taxesIncome taxes14 10 (4)Income taxes9 2 (7)24 12 (12)
Net incomeNet income$206 $167 $39 Net income$133 $104 $29 $339 $271 $68 
Three Months Ended March 31,June 30, 2022 Compared to Three Months Ended March 31,June 30, 2021. Net income increased by $39$29 million, primarily due to increases in electric and gas distribution rates,rates.
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net income increased by $68 million, primarily due to increases in electric and volume.gas distribution rates.
The changes in Operating revenues consisted of the following:
Three Months Ended
March 31, 2022		Three Months Ended
June 30, 2022		Six Months Ended
June 30, 2022
(Decrease) Increase(Decrease) Increase(Decrease) Increase
ElectricGasTotalElectricGasTotalElectricGasTotal
WeatherWeather$(4)$(5)$(9)Weather$(1)$(1)$(2)$(5)$(5)$(10)
VolumeVolume7 7 14 Volume(2)4 2 4 10 14 
PricingPricing33 17 50 Pricing32 6 38 65 23 88 
TransmissionTransmission5 — 5 Transmission3 — 3 8 — 8 
OtherOther5 3 8 Other6 1 7 11 4 15 
46 22 68 38 10 48 83 32 115 
Regulatory required programsRegulatory required programs36 54 90 Regulatory required programs58 17 75 95 71 166 
Total increaseTotal increase$82 $76 $158 Total increase$96 $27 $123 $178 $103 $281 
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 March 31,June 30, 2022 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
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PECO’s service territory for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021 and normal weather consisted of the following:
Three Months Ended March 31,% ChangeThree Months Ended June 30,% Change
PECO Service TerritoryPECO Service Territory20222021Normal2022 vs. 20212022 vs. NormalPECO Service Territory20222021Normal2022 vs. 20212022 vs. Normal
Heating Degree-DaysHeating Degree-Days385404424(4.7)%(9.2)%
Cooling Degree-DaysCooling Degree-Days4344183913.8 %11.0 %
Six Months Ended June 30,% Change
20222021Normal2022 vs. 20212022 vs. Normal
Heating Degree-DaysHeating Degree-Days2,228 2,3022,416(3.2)%(7.8)%Heating Degree-Days2,613 2,7062,840(3.4)%(8.0)%
Cooling Degree-DaysCooling Degree-Days1 51(80.0)%— %Cooling Degree-Days435 4233922.8 %11.0 %
Volume. Electric volume, exclusive of the effects of weather, for the three and six months ended March 31,June 30, 2022, compared to the same period in 2021, increased on a net basis due to an increase in overall usage for customers further increased by customer growth.remained relatively consistent. Natural gas volume for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021, increased due to retail load growth.
Electric Retail Deliveries to Customers (in GWhs)Electric Retail Deliveries to Customers (in GWhs)Three Months Ended March 31,% Change
Weather -
Normal
% Change(b)
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)
20222021% Change2021% Change20222021% Change
ResidentialResidential3,7583,767(0.2)%1.1 %Residential3,0603,116(1.8)%(1.1)%6,8186,883(0.9)%0.1 %
Small commercial & industrialSmall commercial & industrial1,9371,8813.0 %3.4 %Small commercial & industrial1,8131,7583.1 %3.0 %3,7503,6393.1 %3.2 %
Large commercial & industrialLarge commercial & industrial3,3323,2721.8 %1.9 %Large commercial & industrial3,4163,475(1.7)%(1.8)%6,7486,747— %— %
Public authorities & electric railroadsPublic authorities & electric railroads18214922.1 %22.4 %Public authorities & electric railroads13512111.6 %11.9 %31727017.4 %17.7 %
Total electric retail deliveries(a)
Total electric retail deliveries(a)
9,2099,0691.5 %2.2 %
Total electric retail deliveries(a)
8,4248,470(0.5)%(0.4)%17,63317,5390.5 %1.0 %
As of March 31,As of June 30,
Number of Electric CustomersNumber of Electric Customers20222021Number of Electric Customers20222021
ResidentialResidential1,521,2551,512,255Residential1,521,7281,513,456
Small commercial & industrialSmall commercial & industrial155,485154,637Small commercial & industrial155,484154,842
Large commercial & industrialLarge commercial & industrial3,1023,109Large commercial & industrial3,1143,108
Public authorities & electric railroadsPublic authorities & electric railroads10,34210,237Public authorities & electric railroads10,38610,285
TotalTotal1,690,1841,680,238Total1,690,7121,681,691
__________
(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
March 31,		% Change
Weather -
Normal
% Change(b)
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)
20222021% Change2021% Change20222021% Change
ResidentialResidential20,83720,6740.8 %4.3 %Residential5,2065,0273.6 %4.9 %26,04325,7011.3 %4.4 %
Small commercial & industrialSmall commercial & industrial10,54610,1703.7 %5.8 %Small commercial & industrial3,6383,12116.6 %17.2 %14,18413,2916.7 %8.4 %
Large commercial & industrialLarge commercial & industrial10742.9 %10.2 %Large commercial & industrial42100.0 %12.6 %14955.6 %11.4 %
TransportationTransportation7,6397,650(0.1)%0.7 %Transportation5,7075,4684.4 %5.7 %13,34613,1181.7 %2.7 %
Total natural gas retail deliveries(a)
Total natural gas retail deliveries(a)
39,03238,5011.4 %4.0 %
Total natural gas retail deliveries(a)
14,55513,6186.9 %8.0 %53,58752,1192.8 %5.0 %
 As of March 31,
Number of Natural Gas Customers20222021
Residential499,188493,857
Small commercial & industrial44,95944,604
Large commercial & industrial55
Transportation664685
Total544,816539,151
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PECO
 As of June 30,
Number of Natural Gas Customers20222021
Residential499,678494,895
Small commercial & industrial44,72644,450
Large commercial & industrial106
Transportation659677
Total545,073540,028
__________
(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.

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PECO
Pricing for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021 increased primarily due to an increaseincreases in electric and gas distribution rates charged to customers.
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.
Other revenue primarily includes revenue related to late payment charges. Other revenuesrevenue for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021 remained relatively consistent.increased primarily due to revenue related to late payment charges.
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 $91$76 million and $166 million for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021, respectively, 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, 2022
Increase (Decrease)
BSC costs$10 
Credit loss expense3 
Storm-related costs2 
Labor, other benefits, contracting and materials(2)
Pension and non-pension post retirement benefit expense(1)
Other(2)
10 
Regulatory required programs3 
Total increase$13 

The changes in Depreciation and amortization expense consisted of the following:
Three Months Ended
March 31, 2022
Increase
Depreciation and amortization(a)
$6 
Regulatory asset amortization— 
Total increase$6 
__________
(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.
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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 expense1 5 
Storm-related costs1 3 
Pension and non-pension post retirement benefit expense(3)(4)
Labor, other benefits, contracting and materials(6)(8)
Other4 3 
4 15 
Regulatory required programs2 5 
Total increase$6 $20 

The changes in Depreciation and amortization expense consisted of the following:
Three Months Ended June 30, 2022Six Months Ended
June 30, 2022
IncreaseIncrease
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 $3$1 million and $4 million for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021, primarily due to the issuance of debt in 2021.2021 and 2022.
Effective income tax rates were 6.4%6.3% and 5.6%1.9% for the three months ended March 31,June 30, 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.
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BGE

Results of Operations — BGE
Three Months Ended
March 31,		Favorable
(Unfavorable)
Variance		Three Months Ended
June 30,		Favorable
(Unfavorable)
Variance		Six Months Ended
June 30,		Favorable
(Unfavorable)
Variance
2022202120222021Favorable
(Unfavorable)
Variance		20222021Favorable
(Unfavorable)
Variance
Operating revenuesOperating revenues$1,154 $974 $180 Operating revenues$786 $682 $104 $1,940 $1,656 $284 
Operating expensesOperating expensesOperating expenses
Purchased power and fuelPurchased power and fuel454 331 (123)Purchased power and fuel289 219 (70)743 550 (193)
Operating and maintenanceOperating and maintenance218 197 (21)Operating and maintenance205 193 (12)423 390 (33)
Depreciation and amortizationDepreciation and amortization171 152 (19)Depreciation and amortization152 141 (11)322 293 (29)
Taxes other than income taxesTaxes other than income taxes76 72 (4)Taxes other than income taxes71 67 (4)148 139 (9)
Total operating expensesTotal operating expenses919 752 (167)Total operating expenses717 620 (97)1,636 1,372 (264)
Operating incomeOperating income235 222 13 Operating income69 62 7 304 284 20 
Other income and (deductions)Other income and (deductions)Other income and (deductions)
Interest expense, netInterest expense, net(35)(34)(1)Interest expense, net(36)(34)(2)(71)(67)(4)
Other, netOther, net7 8 (1)Other, net5 9 (4)11 16 (5)
Total other income and (deductions)Total other income and (deductions)(28)(26)(2)Total other income and (deductions)(31)(25)(6)(60)(51)(9)
Income before income taxesIncome before income taxes207 196 11 Income before income taxes38 37 1 244 233 11 
Income taxesIncome taxes9 (13)(22)Income taxes1 (8)(9)10 (21)(31)
Net incomeNet income$198 $209 $(11)Net income$37 $45 $(8)$234 $254 $(20)
Three Months Ended March 31,June 30, 2022 Compared to Three Months Ended March 31,June 30, 2021. Net income decreased $8 million primarily due to an increase in depreciation expense, partially offset by 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 $11$20 million primarily due to an increase in depreciation expense and credit loss expense, partially offset by 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.
The changes in Operating revenues consisted of the following:
Three Months Ended
March 31, 2022		Three Months Ended
June 30, 2022		Six Months Ended
June 30, 2022
IncreaseIncreaseIncrease
ElectricGasTotalElectricGasTotalElectricGasTotal
DistributionDistribution$14 $10 $24 Distribution$17 $5 $22 $31 $15 $46 
TransmissionTransmission5 — 5 Transmission2 — 2 7 — 7 
OtherOther8 2 10 Other3 2 5 10 5 15 
27 12 39 22 7 29 48 20 68 
Regulatory required programsRegulatory required programs78 63 141 Regulatory required programs50 25 75 128 88 216 
Total increaseTotal increase$105 $75 $180 Total increase$72 $32 $104 $176 $108 $284 
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 Customers20222021
Residential1,199,272 1,192,470 
Small commercial & industrial115,363 114,819 
Large commercial & industrial12,674 12,505 
Public authorities & electric railroads268 266 
Total1,327,577 1,320,060 
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BGE

As of March 31, As of June 30,
Number of Natural Gas Customers20222021
Number of Electric CustomersNumber of Electric Customers20222021
ResidentialResidential653,397 648,824 Residential1,200,397 1,192,135 
Small commercial & industrialSmall commercial & industrial38,356 38,318 Small commercial & industrial115,769 114,682 
Large commercial & industrialLarge commercial & industrial6,193 6,120 Large commercial & industrial12,721 12,528 
Public authorities & electric railroadsPublic authorities & electric railroads267 267 
TotalTotal697,946 693,262 Total1,329,154 1,319,612 
As of June 30,
Number of Natural Gas Customers20222021
Residential653,409 647,534 
Small commercial & industrial38,227 38,223 
Large commercial & industrial6,211 6,132 
Total697,847 691,889 
Distribution Revenue increased for the three and six months ended March 31,June 30, 2022, compared to the same period in 2021, 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 March 31,June 30, 2022, compared to the same period in 2021, primarily due to the increases in underlying costs and capital investments.
Other Revenue includes 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 March 31,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.
TheThe increase of $123$70 million and $193 million for t thehe three and six months ended March 31,June 30, 2022 compared to the same period in 2021, in Purchased power and fuel expense is fully offset in Operating revenues as part of regulatory required programs.

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BGE

The changes in Operating and maintenance expense consisted of the following:
Three Months Ended
March 31, 2022
 Increase (Decrease)
Labor, other benefits, contracting, and materials$4 
Pension and non-pension postretirement benefits expense(3)
BSC costs8 
Credit loss expense14 
Other(3)
20 
Regulatory required programs1 
Total increase$21 
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 costs6 14 
Credit loss expense— 14 
Other5 2 
11 30 
Regulatory required programs1 3 
Total increase$12 $33 
The changes in Depreciation and amortization expense consisted of the following:
Three Months Ended
March 31, 2022
Increase
Depreciation and amortization(a)
$9 
Regulatory required programs7 
Regulatory asset amortization3 
Total increase$19 
Three Months Ended
June 30, 2022		Six Months Ended
June 30, 2022
IncreaseIncrease
Depreciation and amortization(a)
$9 $19 
Regulatory required programs1 8 
Regulatory asset amortization1 2 
Total increase$11 $29 
__________
(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.

Taxes other than income taxes increased by $4 million and $9 million for the three and six months ended June 30, 2022, respectively, compared to the same period in 2021, primarily due to increased property taxes.
Effective income tax rates were 4.3%2.6% and (6.6)(21.6)% for the three months ended March 31,June 30, 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 decreases in the multi-year plans' accelerated income tax benefits in 2022 as compared to 2021. 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.
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PHI
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 March 31,June 30, 2022 compared to the same period in 2021. See the Results of Operations for Pepco, DPL, and ACE for additional information.
Three Months Ended March 31,Favorable (Unfavorable) VarianceThree Months Ended
June 30,		(Unfavorable) VarianceSix Months Ended June 30,(Unfavorable) Favorable Variance
2022202120222021(Unfavorable) Variance20222021(Unfavorable) Favorable Variance
PHIPHI$130 $128 $2 PHI$100 $141 $(41)$230 $269 $(39)
PepcoPepco46 59 (13)Pepco70 75 (5)116 134 (18)
DPLDPL56 56 — DPL21 30 (9)77 86 (9)
ACEACE26 14 12 ACE11 37 (26)37 51 (14)
Other(a)
Other(a)
2 (1)3 
Other(a)
(2)(1)(1)— (2)2 
___________________
(a)Primarily includes eliminating and consolidating adjustments, PHI's corporate operations, shared service entities, and other financing and investing activities.

Three Months Ended March 31,June 30, 2022 Compared to Three Months Ended March 31,June 30, 2021. Net Incomedecreased by $41 million increased by $2 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's Maryland and District of Columbia multi-year plans and higher electric distribution rates at DPL 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, partially offset by 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 expense.and amortization expense, interest expense, and timing of excess deferred tax amortization at Pepco and ACE, partially offset by favorable impacts as a result of Pepco's Maryland and District of Columbia multi-year plans and higher electric distribution rate at DPL and ACE.

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Pepco

Results of Operations — Pepco
Three Months Ended March 31,Favorable (Unfavorable) VarianceThree Months Ended June 30, Favorable (Unfavorable) VarianceSix Months Ended June 30,Favorable (Unfavorable) Variance
2022202120222021 Favorable (Unfavorable) Variance20222021Favorable (Unfavorable) Variance
Operating revenuesOperating revenues$614 $553 Operating revenues$581 $523 $58 $1,195 $1,076 $119 
Operating expensesOperating expensesOperating expenses
Purchased powerPurchased power213 166 (47)Purchased power162 133 (29)375 298 (77)
Operating and maintenanceOperating and maintenance131 108 (23)Operating and maintenance128 113 (15)260 221 (39)
Depreciation and amortizationDepreciation and amortization108 102 (6)Depreciation and amortization105 96 (9)213 199 (14)
Taxes other than income taxesTaxes other than income taxes95 90 (5)Taxes other than income taxes92 87 (5)186 177 (9)
Total operating expensesTotal operating expenses547 466 (81)Total operating expenses487 429 (58)1,034 895 (139)
Operating incomeOperating income67 87 (20)Operating income94 94 — 161 181 (20)
Other income and (deductions)Other income and (deductions)Other income and (deductions)
Interest expense, netInterest expense, net(36)(34)(2)Interest expense, net(38)(35)(3)(74)(69)(5)
Other, netOther, net13 12 1 Other, net13 13 — 26 25 1 
Total other income and (deductions)Total other income and (deductions)(23)(22)(1)Total other income and (deductions)(25)(22)(3)(48)(44)(4)
Income before income taxesIncome before income taxes44 65 (21)Income before income taxes69 72 (3)113 137 (24)
Income taxesIncome taxes(2)6 8 Income taxes(1)(3)(2)(3)3 6 
Net incomeNet income$46 $59 $(13)Net income$70 $75 $(5)$116 $134 $(18)

Three Months Ended March 31,June 30, 2022Compared to Three Months Ended March 31,June 30, 2021. Net Income decreased by$5 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 and District of Columbia multi-year plans.
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net income decreased $13by $18 million primarily due to an increase in storm costs, depreciation expense, and 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.
The changes in Operating revenues consisted of the following:
Three Months Ended March 31, 2022
Increase (Decrease)
Distribution$6 
Transmission3 
Other(3)
6 
Regulatory required programs55 
Total increase$61 
Three Months Ended
June 30, 2022		Six Months Ended June 30, 2022
IncreaseIncrease
Distribution$20 $26 
Transmission5 8 
Other4 — 
29 34 
Regulatory required programs29 85 
Total increase$58 $119 
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) 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 Customers20222021
Residential846,258 835,415 
Small commercial & industrial54,509 53,738 
Large commercial & industrial22,620 22,492 
Public authorities & electric railroads184 174 
Total923,571 911,819 
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Pepco

As of June 30,
Number of Electric Customers20222021
Residential850,569 837,744 
Small commercial & industrial54,349 53,669 
Large commercial & industrial22,771 22,579 
Public authorities & electric railroads194 178 
Total927,883 914,170 
Distribution Revenue increased for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021 primarily due to favorable impacts of the Maryland and District of Columbia multi-year plans.
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Pepco

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 March 31,June 30, 2022, compared to the same period in 2021, 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 $47$29 million and $77 million for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021, respectively, 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 March 31, 2022
Increase
Storm-related costs$6 
BSC and PHISCO Costs6 
Credit loss expense4 
Labor, other benefits, contracting and materials4 
Other3 
23 
Regulatory required programs— 
Total increase$23 
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 expense5 9 
Storm-related costs— 6 
Other(5)2 
13 37 
Regulatory required programs2 2 
Total increase$15 $39 
__________
(a) Primarily reflects higher contracting costs partially due to timing of maintenance projects.
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Pepco

The changes in Depreciation and amortization expense consisted of the following:
Three Months Ended March 31, 2022
Increase (Decrease)
Depreciation and amortization(a)
$5 
Regulatory asset amortization(4)
Regulatory required programs5 
Total increase$6 
Three Months Ended
June 30, 2022		Six Months Ended June 30, 2022
IncreaseIncrease (Decrease)
Depreciation and amortization(a)
$6 $11 
Regulatory asset amortization2 (3)
Regulatory required programs1 6 
Total increase$9 $14 
___________________
(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.

Effective income tax rates were (4.5)(1.4)% and 9.2%(4.2)% for the three months ended March 31,June 30, 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.
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Results of Operations — DPL
Three Months Ended March 31,Favorable (Unfavorable) VarianceThree Months Ended June 30,Favorable (Unfavorable) VarianceSix Months Ended June 30,Favorable (Unfavorable) Variance
2022202120222021Favorable (Unfavorable) Variance20222021Favorable (Unfavorable) Variance
Operating revenuesOperating revenues$431 $382 Operating revenues$332 $298 $34 $763 $680 $83 
Operating expensesOperating expensesOperating expenses
Purchased power and fuelPurchased power and fuel189 156 (33)Purchased power and fuel135 108 (27)324 263 (61)
Operating and maintenanceOperating and maintenance93 83 (10)Operating and maintenance88 80 (8)181 164 (17)
Depreciation and amortizationDepreciation and amortization57 53 (4)Depreciation and amortization56 51 (5)113 104 (9)
Taxes other than income taxesTaxes other than income taxes18 17 (1)Taxes other than income taxes17 16 (1)35 33 (2)
Total operating expensesTotal operating expenses357 309 (48)Total operating expenses296 255 (41)653 564 (89)
Operating incomeOperating income74 73 1 Operating income36 43 (7)110 116 (6)
Other income and (deductions)Other income and (deductions)Other income and (deductions)
Interest expense, netInterest expense, net(16)(15)(1)Interest expense, net(17)(16)(1)(33)(30)(3)
Other, netOther, net2 3 (1)Other, net4 4 — 6 6 — 
Total other income and (deductions)Total other income and (deductions)(14)(12)(2)Total other income and (deductions)(13)(12)(1)(27)(24)(3)
Income before income taxesIncome before income taxes60 61 (1)Income before income taxes23 31 (8)83 92 (9)
Income taxesIncome taxes4 5 1 Income taxes2 1 (1)6 6 — 
Net incomeNet income$56 $56 $— Net income$21 $30 $(9)$77 $86 $(9)
Three Months Ended March 31,June 30, 2022 Compared to Three Months Ended March 31,June 30, 2021. Net income decreased $9 million primarily due to an increase in depreciation expense and various operating expenses partially offset by higher electric distribution rates.
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net income remained consistent.decreased $9 million primarily due to an increase in credit loss expense, depreciation expense, and various operating expenses, partially offset by higher electric distribution rates.
The changes in Operating revenues consisted of the following:
Three Months Ended
March 31, 2022		Three Months Ended
June 30, 2022		Six Months Ended
June 30, 2022
Increase(Decrease) Increase(Decrease) Increase
ElectricGasTotalElectricGasTotalElectricGasTotal
WeatherWeather$(1)$— $(1)$(1)$— $(1)
VolumeVolume$5 $1 $6 Volume(1)2 1 3 3 6 
DistributionDistribution6 2 8 Distribution5 1 6 10 3 13 
TransmissionTransmission2 — 2 Transmission(1)— (1)2 — 2 
13 3 16 2 3 5 14 6 20 
Regulatory required programsRegulatory required programs25 8 33 Regulatory required programs18 11 29 43 20 63 
Total increaseTotal increase$38 $11 $49 Total increase$20 $14 $34 $57 $26 $83 
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) 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, 2022 compared to the same period in 2021, Operating revenues related to weather remained consistent.
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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's Delaware electric service territory and a 30-year period in DPL's Delaware natural gas service territory. The changes in heating and cooling degree days in DPL’s Delaware service territory for the three and six months ended March 31,June 30, 2022 compared to same period in 2021 and normal weather consisted of the following:
Three Months Ended March 31,% ChangeThree Months Ended June 30,% Change
Delaware Electric Service TerritoryDelaware Electric Service Territory20222021Normal2022 vs. 20212022 vs. NormalDelaware Electric Service Territory20222021Normal2022 vs. 20212022 vs. Normal
Heating Degree-DaysHeating Degree-Days441 480 471 (8.1)%(6.4)%
Cooling Degree-DaysCooling Degree-Days328 361 336 (9.1)%(2.4)%
Six Months Ended June 30,% Change
20222021Normal2022 vs. 20212022 vs. Normal
Heating Degree-DaysHeating Degree-Days2,355 2,358 2,480 (0.1)%(5.0)%Heating Degree-Days2,796 2,838 2,951 (1.5)%(5.3)%
Cooling Degree-DaysCooling Degree-Days3 3 — — %— %Cooling Degree-Days331 364 336 (9.1)%(1.5)%
Three Months Ended March 31,% ChangeThree Months Ended June 30,% Change
Delaware Natural Gas Service TerritoryDelaware Natural Gas Service Territory20222021Normal2022 vs. 20212022 vs. NormalDelaware Natural Gas Service Territory20222021Normal2022 vs. 20212022 vs. Normal
Heating Degree-DaysHeating Degree-Days441 480 492 (8.1)%(10.4)%
Six Months Ended June 30,% Change
20222021Normal2022 vs. 20212022 vs. Normal
Heating Degree-DaysHeating Degree-Days2,355 2,358 2,500 (0.1)%(5.8)%Heating Degree-Days2,796 2,838 2,993 (1.5)%(6.6)%
Volume, exclusive of the effects of weather, increasedremained relatively consistent for the three months ended March 31,June 30, 2022 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.
Electric Retail Deliveries to Delaware Customers (in GWhs)Electric Retail Deliveries to Delaware Customers (in GWhs)Three Months Ended
March 31,		% Change
Weather - Normal
% Change(b)
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)
202220212022202120222021
ResidentialResidential895 854 4.8 %4.2 %Residential675 703 (4.0)%(1.7)%1,570 1,557 0.8 %1.6 %
Small commercial & industrialSmall commercial & industrial370 342 8.2 %7.7 %Small commercial & industrial337 357 (5.6)%(4.8)%706 699 1.0 %1.4 %
Large commercial & industrialLarge commercial & industrial765 689 11.0 %11.0 %Large commercial & industrial773 810 (4.6)%(4.2)%1,538 1,499 2.6 %2.8 %
Public authorities & electric railroadsPublic authorities & electric railroads9 9 — %5.3 %Public authorities & electric railroads8 10 (20.0)%(19.9)%17 19 (10.5)%(7.9)%
Total electric retail deliveries(a)
Total electric retail deliveries(a)
2,039 1,894 7.7 %7.3 %
Total electric retail deliveries(a)
1,793 1,880 (4.6)%(3.5)%3,831 3,774 1.5 %2.0 %
As of March 31,As of June 30,
Number of Total Electric Customers (Maryland and Delaware)Number of Total Electric Customers (Maryland and Delaware)20222021Number of Total Electric Customers (Maryland and Delaware)20222021
ResidentialResidential478,009 473,917 Residential479,728 475,061 
Small commercial & industrialSmall commercial & industrial63,296 62,647 Small commercial & industrial63,574 62,880 
Large commercial & industrialLarge commercial & industrial1,221 1,208 Large commercial & industrial1,222 1,213 
Public authorities & electric railroadsPublic authorities & electric railroads603 608 Public authorities & electric railroads598 607 
TotalTotal543,129 538,380 Total545,122 539,761 
___________________
(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)
20222021
Residential4,453 4,394 1.3 %0.3 %
Small commercial & industrial1,983 1,868 6.2 %6.0 %
Large commercial & industrial457 457 — %0.1 %
Transportation2,207 2,224 (0.8)%(0.7)%
Total natural gas deliveries(a)
9,100 8,943 1.8 %1.3 %
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As of March 31,
Number of Delaware Natural Gas Customers20222021
Natural Gas Retail Deliveries to Delaware Customers (in mmcf)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)
2022202120222021
ResidentialResidential128,695 127,522 Residential983 713 37.9 %44.6 %5,436 5,107 6.4 %6.3 %
Small commercial & industrialSmall commercial & industrial10,097 10,043 Small commercial & industrial570 430 32.6 %39.2 %2,550 2,295 11.1 %12.0 %
Large commercial & industrialLarge commercial & industrial17 19 Large commercial & industrial402 393 2.3 %2.3 %863 853 1.2 %1.1 %
TransportationTransportation159 160 Transportation1,444 1,470 (1.8)%(0.7)%3,650 3,694 (1.2)%(0.7)%
Total138,968 137,744 
Total natural gas deliveries(a)
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,
Number of Delaware Natural Gas Customers20222021
Residential128,715 127,503 
Small commercial & industrial10,068 9,953 
Large commercial & industrial16 18 
Transportation157 158 
Total138,956 137,632 
__________
(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 March 31,June 30, 2022 compared to the same period in 2021 primarily due to higher electric distribution rates in Maryland that became effective in March 2022, higher Distribution System Improvement Charge (DSIC) rates in Delaware that became effective in January 2022, and higher approved electric distribution rates in Delaware that became effective in September 2021.
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 increasedremained relatively consistent for the three months ended March 31,June 30, 2022 compared to the same period in 2021. 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.
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See Note 5 — Segment Information of the Combined Notes to Consolidated Financial Statements for the presentation of DPL's revenue disaggregation.
The increase of $33$27 million and $61 million for the three and six months ended March 31,June 30, 2022, compared to the same period in 2021, respectively, in Purchased power and fuel expense is fully offset in Operating revenues as part of regulatory required programs.
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The changes in Operating and maintenance expense consisted of the following:
Three Months Ended
March 31, 2022
Increase
BSC and PHISCO costs$3 
Storm-related costs3 
Credit loss expense2 
Labor, other benefits, contracting and materials(2)
Other3 
9 
Regulatory required programs1 
Total increase$10 
Three Months Ended
June 30, 2022		Six Months Ended
June 30, 2022
Increase (Decrease)Increase
BSC and PHISCO costs$4 $7 
Credit loss expense2 4 
Storm-related costs— 3 
Labor, other benefits, contracting and materials2 1 
Other(1)— 
7 15 
Regulatory required programs1 2 
Total increase$8 $17 
The changes in Depreciation and amortization expense consisted of the following:
Three Months Ended
March 31, 2022
Increase
Depreciation and amortization(a)
$3 
Regulatory asset amortization— 
Regulatory required programs1 
Total increase$4 
Three Months Ended
June 30, 2022		Six Months Ended
June 30, 2022
IncreaseIncrease (Decrease)
Depreciation and amortization(a)
$5 $9 
Regulatory asset amortization— (1)
Regulatory required programs— 1 
Total increase$5 $9 
___________________
(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.

Effective income tax rates were 6.7%8.7% and 8.2%3.2% for the three months ended March 31,June 30, 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.
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Results of Operations — ACE
Three Months Ended March 31,Favorable (Unfavorable) VarianceThree Months Ended June 30,(Unfavorable)Favorable VarianceSix Months Ended June 30,Favorable (Unfavorable) Variance
2022202120222021(Unfavorable)Favorable Variance20222021Favorable (Unfavorable) Variance
Operating revenuesOperating revenues$349 $310 $39 Operating revenues$309 $319 $(10)$658 $629 $29 
Operating expensesOperating expensesOperating expenses
Purchased powerPurchased power178 157 (21)Purchased power123 154 31 301 311 10 
Operating and maintenanceOperating and maintenance84 76 (8)Operating and maintenance86 73 (13)170 150 (20)
Depreciation and amortizationDepreciation and amortization47 47 — Depreciation and amortization72 40 (32)118 87 (31)
Taxes other than income taxesTaxes other than income taxes2 2 — Taxes other than income taxes2 2 — 4 4 — 
Total operating expensesTotal operating expenses311 282 (29)Total operating expenses283 269 (14)593 552 (41)
Operating incomeOperating income38 28 10 Operating income26 50 (24)65 77 (12)
Other income and (deductions)Other income and (deductions)Other income and (deductions)
Interest expense, netInterest expense, net(14)(15)1 Interest expense, net(17)(14)(3)(32)(29)(3)
Other, netOther, net3 1 2 Other, net2 — 2 5 2 3 
Total other income and (deductions)Total other income and (deductions)(11)(14)3 Total other income and (deductions)(15)(14)(1)(27)(27)— 
Income before income taxesIncome before income taxes27 14 13 Income before income taxes11 36 (25)38 50 (12)
Income taxesIncome taxes1 — (1)Income taxes— (1)(1)1 (1)(2)
Net incomeNet income$26 $14 $12 Net income$11 $37 $(26)$37 $51 $(14)

Three Months Ended March 31,June 30, 2022 Compared to Three Months Ended March 31,June 30, 2021. Net income decreased by $26 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.
Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net income increased $12decreased 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.
The changes in Operating revenues consisted of the following:
Three Months Ended March 31, 2022
 Increase
Weather$1 
Volume2 
Distribution11 
Transmission5 
19 
Regulatory required programs20 
Total increase$39 
Three Months Ended
June 30, 2022		Six Months Ended June 30, 2022
(Decrease) Increase(Decrease) Increase
Weather$(3)$(3)
Volume(13)(11)
Distribution8 20 
Transmission(3)3 
(11)9 
Regulatory required programs1 20 
Total (decrease) increase$(10)$29 
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 Conservation Incentive Program (CIP)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.
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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 March 31,June 30, 2022 compared to the same period in 2021, Operating revenues related to weather increaseddecreased due to the absence of favorable impacts in the first and second quarter of 2022 as a result of the CIP.
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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 March 31,June 30, 2022 compared to same period in 2021 and normal weather consisted of the following:
Three Months Ended March 31,Normal% ChangeThree Months Ended June 30,Normal% Change
Heating and Cooling Degree-DaysHeating and Cooling Degree-Days202220212022 vs. 20212022 vs. NormalHeating and Cooling Degree-Days202220212022 vs. 20212022 vs. Normal
Heating Degree-DaysHeating Degree-Days2,436 2,348 2,454 3.7 %(0.7)%Heating Degree-Days533 525 540 1.5 %(1.3)%
Cooling Degree-DaysCooling Degree-Days2 4 1 (50.0)%100.0 %Cooling Degree-Days275 321 305 (14.3)%(9.8)%
Six Months Ended June 30,Normal% Change
Heating and Cooling Degree-Days202220212022 vs. 20212022 vs. Normal
Heating Degree-Days2,969 2,873 2,994 3.3 %(0.8)%
Cooling Degree-Days277 325 305 (14.8)%(9.2)%
Volume, exclusive of the effects of weather, increaseddecreased for the three and six months ended March 31,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)Electric Retail Deliveries to Customers (in GWhs)Three Months Ended
March 31,		% Change
Weather - Normal % Change(b)
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)
202220212022202120222021
ResidentialResidential918 928 (1.1)%(2.3)%Residential859 975 (11.9)%(9.7)%1,777 1,903 (6.6)%(6.0)%
Small commercial & industrialSmall commercial & industrial339 305 11.1 %9.7 %Small commercial & industrial362 333 8.7 %9.7 %701 638 9.9 %9.7 %
Large commercial & industrialLarge commercial & industrial703 716 (1.8)%(2.4)%Large commercial & industrial808 761 6.2 %6.7 %1,511 1,477 2.3 %2.3 %
Public authorities & electric railroadsPublic authorities & electric railroads14 13 7.7 %6.2 %Public authorities & electric railroads11 11 — %(5.8)%25 24 4.2 %0.6 %
Total electric retail deliveries(a)
Total electric retail deliveries(a)
1,974 1,962 0.6 %(0.4)%
Total electric retail deliveries(a)
2,040 2,080 (1.9)%(0.5)%4,014 4,042 (0.7)%(0.5)%

As of March 31,As of June 30,
Number of Electric CustomersNumber of Electric Customers20222021Number of Electric Customers20222021
ResidentialResidential500,511 498,396 Residential501,494 499,436 
Small commercial & industrialSmall commercial & industrial62,124 61,771 Small commercial & industrial62,291 61,836 
Large commercial & industrialLarge commercial & industrial3,124 3,267 Large commercial & industrial3,085 3,243 
Public authorities & electric railroadsPublic authorities & electric railroads724 704 Public authorities & electric railroads726 707 
TotalTotal566,483 564,138 Total567,596 565,222 
___________________
(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.
Distribution Revenue increased for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021 due to higher distribution rates that becomebecame effective in January 2022.
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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 increaseddecreased for the three months ended March 31,June 30, 2022 compared to the same period in 2021, primarily due to decreases in underlying costs, partially offset by increases in capital investment and underlying costs.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, and mutual assistance revenues.
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, 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
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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 increasedecrease of $21$31 million and $10 million for the three and six months ended March 31,June 30, 2022 compared to the same period in 2021, respectively, in Purchased power expense is fully offset in Operating revenues as part of regulatory required programs.
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The changes in Operating and maintenance expense consisted of the following:
Three Months Ended March 31, 2022
Increase
BSC and PHISCO costs$2 
Labor, other benefits, contracting and materials1 
Storm-related costs1 
4 
Regulatory required programs(a)
4 
Total increase$8 
Three Months Ended
June 30, 2022		Six Months Ended June 30, 2022
IncreaseIncrease
Labor, other benefits, contracting and materials$4 $4 
BSC and PHISCO costs3 4 
Storm-related costs1 2 
Credit loss expense1 — 
Other1 3 
10 13 
Regulatory required programs(a)
3 7 
Total increase$13 $20 
___________________
(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 March 31, 2022
Increase (Decrease)
Depreciation and amortization(a)
$3 
Regulatory asset amortization1 
Regulatory required programs(4)
Total$— 
Three Months Ended
June 30, 2022		Six Months Ended June 30, 2022
IncreaseIncrease
Depreciation and amortization(a)
$4 $7 
Regulatory asset amortization— 1 
Regulatory required programs(b)
28 23 
Total increase$32 $31 
___________________
(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.
(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 3.7%0.0% and 0.0%(2.8)% for the three months ended March 31,June 30, 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 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.
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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 Constellation have not been presented as discontinued operations and are included in the Consolidated Statements of Cash Flows for all periods presented. The Exelon Consolidated Statement of Cash Flows for the threesix months ended March 31,June 30, 2022 includes one month of cash flows from Generation. The Exelon Consolidated Statement of Cash Flows for the threesix months ended March 31,June 30, 2021 includes threesix 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.
See Note 3 — Regulatory Matters of the Exelon 2021 Recast Form 10-K and NoteNotes 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.
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The following table provides a summary of the change in cash flows from operating activities for the threesix months ended March 31,June 30, 2022 and 2021 by Registrant:
Increase (decrease) in cash flows from operating activitiesIncrease (decrease) in cash flows from operating activitiesExelonComEdPECOBGE PHIPepcoDPLACEIncrease (decrease) in cash flows from operating activitiesExelonComEdPECOBGE PHIPepcoDPLACE
Net income (loss)Net income (loss)$862 $(9)$39 $(11)$2 $(13)$— $12 Net income (loss)$852 $25 $68 $(20)$(39)$(18)$(9)$(14)
Adjustments to reconcile net income to cash:Adjustments to reconcile net income to cash:Adjustments to reconcile net income to cash:
Non-cash operating activitiesNon-cash operating activities69 20 17 70 66 37 17 11 Non-cash operating activities(714)(2)14 82 164 57 33 72 
Option premiums (paid), netOption premiums (paid), net(55)— — — — — — — Option premiums (paid), net(41)— — — — — — — 
Collateral received, netCollateral received, net869 38 — — — — — — Collateral received, net732 58 — 188 403 85 180 137 
Income taxesIncome taxes(36)21 (3)13 2 (1)(4)(1)Income taxes(167)15 25 — (1)(4)(8)6 
Pension and non-pension postretirement benefit contributionsPension and non-pension postretirement benefit contributions(37)(5)4 9 (31)— (1)(4)Pension and non-pension postretirement benefit contributions(26)(5)2 12 (30)— (1)(4)
Changes in working capital and other noncurrent assets and liabilities1,371 53 (41)67 (16)— 31 (28)
Increase (decrease) in cash flows from operating activities$3,043 $118 $16 $148 $23 $23 $43 $(10)
Changes in regulatory assets and liabilities, netChanges in regulatory assets and liabilities, net(100)(86)(10)25 (38)2 2 (29)
Changes in working capital and other assets and liabilitiesChanges in working capital and other assets and liabilities1,566 25 (61)1 (46)(16)(7)(17)
Increase in cash flows from operating activitiesIncrease in cash flows from operating activities$2,102 $30 $38 $288 $413 $106 $190 $151 
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 threesix months ended March 31,June 30, 2022 and 2021 were as follows:
•See Note 14 — 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 increased due to rising 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.
•See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information on regulatory assets and liabilities.
•Changes in working capital and other noncurrent assets and liabilities for the Utility Registrants and Exelon Corporate total $88$(74) million and for Generation total $1,283$1,640 million. The change for Generation primarily relates to the revolving accounts receivable financing arrangement. See Note 6 — Accounts Receivable of the Exelon 2021 Form 10-K and the Collection of DPP discussion below for additional information.
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Cash Flows from Investing Activities
The following table provides a summary of the change in cash flows from investing activities for the threesix months ended March 31,June 30, 2022 and 2021 by Registrant:
(Decrease) increase in cash flows from investing activitiesExelonComEdPECOBGE PHIPepcoDPLACE
Increase (decrease) in cash flows from investing activitiesIncrease (decrease) in cash flows from investing activitiesExelonComEdPECOBGE PHIPepcoDPLACE
Capital expendituresCapital expenditures$218 $(4)$(49)$33 $47 $2 $9 $36 Capital expenditures$533 $(46)$(81)$42 $113 $37 $17 $60 
Investment in NDT fund sales, netInvestment in NDT fund sales, net3 — — — — — — — Investment in NDT fund sales, net72 — — — — — — — 
Collection of DPPCollection of DPP(1,405)— — — — — — — Collection of DPP(2,040)— — — — — — — 
Proceeds from sales of assets and businessesProceeds from sales of assets and businesses(664)— — — — — — — Proceeds from sales of assets and businesses(708)— — — — — — — 
Changes in intercompany money poolChanges in intercompany money pool— — 48 — — — — — Changes in intercompany money pool— — — — — — (64)— 
Other investing activitiesOther investing activities(66)— 1 1 1 — 1 — Other investing activities(13)3 1 (3)5 4 1 — 
(Decrease) increase in cash flows from investing activities(Decrease) increase in cash flows from investing activities$(1,914)$(4)$— $34 $48 $2 $10 $36 (Decrease) increase in cash flows from investing activities$(2,156)$(43)$(80)$39 $118 $41 $(46)$60 
Significant investing cash flow impacts for the Registrants for threesix months ended March 31,June 30, 2022 and 2021 were as follows:
•Variances 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. 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 DPP relates to the revolving accounts receivable financing agreement which Generation entered into in April of 2020. See Note 6 — Accounts Receivable of the Exelon 2021 Form 10-K for additional information on the transaction and the DPP, including the $400 million of additional funding received in February and March of 2021.
•Proceeds from sales of assets and businesses decreased primarily due to the sale of a significant portion of Generation's solar business in 2021. See Note 2 — Mergers, Acquisitions, and Dispositions of the Exelon 2021 Form 10-K for additional information.
•Changes in intercompany money pool are driven by short-term borrowing needs. Refer below for more information regarding the intercompany money pool.
Cash Flows from Financing Activities
The following table provides a summary of the change in cash flows from financing activities for the threesix months ended March 31,June 30, 2022 and 2021 by Registrant:
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Increase (decrease) in cash flows from financing activitiesIncrease (decrease) in cash flows from financing activitiesExelonComEdPECOBGE PHIPepcoDPLACEIncrease (decrease) in cash flows from financing activitiesExelonComEdPECOBGE PHIPepcoDPLACE
Changes in short-term borrowings, netChanges in short-term borrowings, net$(997)$188 $— $(36)$(100)$(140)$(3)$43 Changes in short-term borrowings, net$369 $290 $210 $(130)$(389)$(251)$(3)$(135)
Long-term debt, netLong-term debt, net2,669 50 (375)— 119 250 — (131)Long-term debt, net1,619 50 (375)(100)124 50 — 74 
Changes in intercompany money poolChanges in intercompany money pool— — 105 — 36 — — — Changes in intercompany money pool— — 40 — 29 64 — — 
Dividends paid on common stockDividends paid on common stock42 (17)(15)(2)— (14)(1)(5)Dividends paid on common stock84 (36)(31)(4)— (177)7 191 
Distributions to memberDistributions to member— — — — (21)— — — Distributions to member— — — — 19 — — — 
Contributions from(to) parent/memberContributions from(to) parent/member— (31)227 — 144 249 24 (130)Contributions from(to) parent/member— (60)(168)186 144 249 24 (130)
Transfer of cash, restricted cash, and cash equivalents to ConstellationTransfer of cash, restricted cash, and cash equivalents to Constellation(2,594)— — — — — — — Transfer of cash, restricted cash, and cash equivalents to Constellation(2,594)— — — — — — — 
Other financing activitiesOther financing activities(38)(1)3 (1)(4)(4)— — Other financing activities(50)(1)(4)(1)(4)(4)(1)— 
Increase (decrease) in cash flows from financing activities$(918)$189 $(55)$(39)$174 $341 $20 $(223)
(Decrease) increase in cash flows from financing activities(Decrease) increase in cash flows from financing activities$(572)$243 $(328)$(49)$(77)$(69)$27 $— 
Significant financing cash flow impacts for the Registrants for the threesix months ended March 31,June 30, 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 to 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 to 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 1917 — Commitments and Contingencies of the Exelon 2021 Recast 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 threesix months ended March 31,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 threesix months ended March 31, 2022, there were no long-term debt retirements or redemptions. However, as of May 9,June 30, 2022, the following long-term debt was retired and/or redeemed:
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Company(a)Company(a)TypeInterest RateMaturityAmountCompany(a)TypeInterest RateMaturityAmount
ExelonExelonJunior Subordinated Notes3.50 %May 2, 2022$1,150 
ExelonExelonLong-Term Software License Agreement3.96 %May 1, 20242 
PECOPECOFirst Mortgage Bonds2.375 %September 15, 2022350 
PepcoPepcoFirst Mortgage Bonds3.05 %April 1, 2022$200 PepcoFirst Mortgage Bonds3.05 %April 1, 2022200 
ExelonJunior Subordinated Notes3.50 %May 2, 20221,150 
__________
(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 threesix months ended March 31,June 30, 2022 and for the secondthird quarter of 2022 were as follows:
PeriodDeclaration DateShareholder of Record DateDividend Payable Date
Cash per Share(a)
First Quarter 2022February 8, 2022February 25, 2022March 10, 2022$0.3375 
Second Quarter 2022April 26, 2022May 13, 2022June 10, 2022$0.3375 
Third Quarter 2022July 26, 2022August 15, 2022September 9, 2022$0.3375 
___________________
(a)Exelon's Board of Directors approved an updated dividend policy for 2022. The 2022 quarterly dividend will be $0.3375 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 $3.7$3.6 billion was available to support additional commercial paper as of March 31,June 30, 2022, and of which no financial institution has more than 7%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 threesix months ended March 31,June 30, 2022 to fund their short-term liquidity needs, when necessary. On February 1, 2022, Exelon Corporate and the Utility Registrants each entered into 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 Exelon 2021 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.
Exelon anticipates issuing up to $1.0 billion of registered shares of common stock through 2025. Exelon plans to establish a $1.0 billion at-the-market (ATM) program, under which Exelon can issue registered shares of common stock through designated broker-dealers at prevailing market prices. Exelon anticipates issuing $500 million in 2022 through the ATM, a one-time common equity offering, or a combination of these methods.
Pursuant to the Separation Agreement between Exelon 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.
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 March 31,June 30, 2022 and available credit facility capacity prior to any incremental collateral at March 31,June 30, 2022:
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PJM Credit Policy Collateral
Other Incremental Collateral Required(a)
Available Credit Facility Capacity Prior to Any Incremental CollateralPJM Credit Policy Collateral
Other Incremental Collateral Required(a)
Available Credit Facility Capacity Prior to Any Incremental Collateral
ComEdComEd$40 $— $998 ComEd$12 $— $995 
PECOPECO2 39 600 PECO2 37 390 
BGEBGE2 62 350 BGE3 75 600 
PepcoPepco2 — 300 Pepco3 — 257 
DPLDPL2 16 300 DPL2 15 300 
ACEACE1 — 300 ACE1 — 300 
___________________
(a)Represents incremental collateral related to natural gas procurement contracts.
Capital Expenditure Spending
As of March 31,June 30, 2022, the most recent estimates of capital expenditures for plant additions and improvements for 2022 are as follows:        
(In millions)TransmissionDistributionGas
Total(a)
ExelonN/AN/AN/A$6,900 
ComEd475 2,000 N/A2,475 
PECO200 800 325 1,325 
BGE250 500 475 1,225 
PHI575 1,200 75 1,850 
Pepco275 675 N/A950 
DPL125 250 75 450 
ACE175 275 N/A450 
__________
(a)Numbers rounded to the nearest $25M and may not sum due to rounding.
(In millions)TransmissionDistributionGasTotal
ExelonN/AN/AN/A$6,900 
ComEd475 2,000 N/A2,475 
PECO200 825 325 1,350 
BGE250 500 475 1,225 
PHI625 1,150 75 1,850 
Pepco275 625 N/A900 
DPL150 250 75 475 
ACE200 275 N/A475 
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 Postretirement 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's estimated annual qualified pension contributions will be approximately $313 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. 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).
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Credit Facilities
Exelon Corporate, ComEd, and BGE meet their short-term liquidity requirements primarily through the issuance of commercial paper. PECO meet theirmeets its short-term liquidity requirements primarily through the issuance of
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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, and DPL did not change for the threesix months ended March 31,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.
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 March 31,June 30, 2022, are presented in the following table. Pepco, ACE and DPL had no activity within the PHI intercompany money pool during the threesix months ended March 31,June 30, 2022.
During the Three Months Ended March 31, 2022As of March 31, 2022
Exelon Intercompany Money PoolMaximum
Contributed		Maximum
Borrowed		Contributed
(Borrowed)
Exelon Corporate$396 $— $312 
PECO— (95)(65)
BSC— (377)(246)
PHI Corporate— (54)(46)
PCI50 — 45 
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During the Six Months Ended June 30, 2022As of June 30, 2022
Exelon Intercompany Money PoolMaximum
Contributed		Maximum
Borrowed		Contributed
(Borrowed)
Exelon Corporate$396 $— $287 
PECO60 (105)— 
BSC— (377)(308)
PHI Corporate— (54)(24)
PCI50 — 45 
During the Six Months Ended June 30, 2022As of June 30, 2022
PHI Intercompany Money PoolMaximum
Contributed		Maximum
Borrowed		Contributed
(Borrowed)
Pepco$— $(85)$(73)
DPL85 — 73 
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. The ability of each Registrant to sell securities off the
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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 March 31, 2022As of June 30, 2022
Short-term Financing AuthorityRemaining Long-term Financing AuthorityShort-term Financing AuthorityRemaining Long-term Financing Authority
CommissionExpiration DateAmountCommissionExpiration DateAmountCommissionExpiration DateAmountCommissionExpiration DateAmount
ComEd(a)
ComEd(a)
FERCDecember 31, 2023$2,500 ICCJanuary 1, 2025$1,343 
ComEd(a)
FERCDecember 31, 2023$2,500 ICCJanuary 1, 2025$1,343 
PECO(b)
PECO(b)
FERCDecember 31, 20231,500 PAPUCDecember 31, 20241,900 
PECO(b)
FERCDecember 31, 20231,500 PAPUCDecember 31, 20241,550 
BGEBGEFERCDecember 31, 2023700 MDPSCN/A500 BGEFERCDecember 31, 2023700 MDPSCN/A— 
Pepco(c)Pepco(c)FERCDecember 31, 2023500 MDPSC / DCPSCDecember 31, 2022225 Pepco(c)FERCDecember 31, 2023500 MDPSC / DCPSC2022 & 20251,625 
DPLDPLFERCDecember 31, 2023500 MDPSC / DEPSCDecember 31, 202247 DPLFERCDecember 31, 2023500 MDPSC / DEPSCDecember 31, 202247 
ACE(c)(d)
ACE(c)(d)
NJBPUDecember 31, 2023350 NJBPUDecember 31, 2022— 
ACE(c)(d)
NJBPUDecember 31, 2023350 NJBPUDecember 31, 2022— 
___________________
(a)On November 18, 2021, ComEd received approval from the ICC for $2 billion in new money long-term debt financing authority with an effective date of January 1, 2022.
(b)On December 2, 2021, PECO received approval from the PAPUC for $2.5 billion in new long-term debt financing authority with an effective date of January 1, 2022.
(c)ACE is currentlyAs of June 30, 2022, Pepco had $225 million in the process of renewing its long-term financing authority withfrom the MDPSC and DCPSC, which has an expiration date of December 31, 2022. On June 9, 2022 and June 30, 2022, Pepco received approval from 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 and has an expiration date of December 31, 2025.
(d)On July 13, 2022, ACE received approval from the NJBPU and expects approval by August 1,for $700 million in new long-term debt financing authority with an effective date of July 20, 2022.

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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 1513 — Retirement Benefits of the Exelon 2021 Recast 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.
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
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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 WithinTotal Fair
Value
202220232024202520262027 and Beyond
Prices based on model or other valuation methods (Level 3)$(1)$(8)$(18)$(18)$(18)$(81)$(144)
Maturities WithinTotal Fair
Value
202220232024202520262027 and Beyond
Prices based on model or other valuation methods (Level 3)$11 $(2)$(14)$(16)$(15)$(52)$(88)
ITEM 4.    CONTROLS AND PROCEDURES
During the firstsecond quarter of 2022, 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 March 31,June 30, 2022, 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 firstsecond quarter of 2022 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 Exelon’sthe 2021 Form 10-K, (b) Notes 3 — Regulatory Matters and (b)17 — Commitments and Contingencies of the 2021 Recast 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 March 31,June 30, 2022, the Registrants' risk factors were consistent with the risk factors described in the Registrants' combined 2021 Form 10-K in ITEM 1A. RISK FACTORS.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
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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.
ITEM 5.    OTHER INFORMATION
Amendments to Exelon Governing Documents
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.

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ITEM 5.    OTHER INFORMATION
All Registrants
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.
Exhibit No.Description
101.INSInline 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.
101.SCHInline XBRL Taxonomy Extension Schema Document.
101.CALInline XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEFInline XBRL Taxonomy Extension Definition Linkbase Document.
101.LABInline XBRL Taxonomy Extension Labels Linkbase Document.
101.PREInline XBRL Taxonomy Extension Presentation Linkbase Document.
104Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
*Filed herewith
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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,June 30, 2022 filed by the following officers for the following companies:
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,June 30, 2022 filed by the following officers for the following companies:
Exhibit No.Description
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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. CRANE/s/    JOSEPH NIGRO
Christopher M. CraneJoseph Nigro
President, Chief Executive Officer
(Principal Executive Officer) and Director		Senior Executive Vice President and Chief Financial Officer
(Principal Financial Officer)
/s/ FABIAN E. SOUZAJOSEPH R. TRPIK
Fabian E. SouzaJoseph R. Trpik
Senior Vice President and Corporate Controller
(Principal Accounting Officer)
May 9,August 3, 2022
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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. QuinionesElisabeth J. Graham
Chief Executive Officer
(Principal Executive Officer)		Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer)
/s/    STEVEN J. CICHOCKI
Steven J. Cichocki
Director, Accounting
(Principal Accounting Officer)
May 9,August 3, 2022
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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. STEFANI
Michael A. InnocenzoRobert J. Stefani
President and Chief Executive Officer
(Principal Executive Officer)		Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer)
/s/    CAROLINE FULGINITI
Caroline Fulginiti
Director, Accounting
(Principal Accounting Officer)
May 9,August 3, 2022

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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. KhouzamiDavid M. Vahos
Chief Executive Officer
(Principal Executive Officer)		Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer)
 /s/ JASON T. JONES
Jason T. Jones
Director, Accounting
(Principal Accounting Officer)
May 9,August 3, 2022

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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 AnthonyPhillip S. Barnett
President and Chief Executive Officer
(Principal Executive Officer)		Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer)
/s/ JULIE E. GIESE
Julie E. Giese
Director, Accounting
(Principal Accounting Officer)
May 9,August 3, 2022

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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 AnthonyPhillip S. Barnett
President and Chief Executive Officer
(Principal Executive Officer)		Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer)
/s/ JULIE E. GIESE
Julie E. Giese
Director, Accounting
(Principal Accounting Officer)
May 9,August 3, 2022

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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 AnthonyPhillip S. Barnett
President and Chief Executive Officer
(Principal Executive Officer)		Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer)
/s/ JULIE E. GIESE
Julie E. Giese
Director, Accounting
(Principal Accounting Officer)
May 9,August 3, 2022

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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 AnthonyPhillip S. Barnett
President and Chief Executive Officer
(Principal Executive Officer)		Senior Vice President, Chief Financial Officer and Treasurer
(Principal Financial Officer)
/s/ JULIE E. GIESE
Julie E. Giese
Director, Accounting
(Principal Accounting Officer)
May 9,August 3, 2022
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