Pepco 10Q 2022 Q2 Quarterly report

0001109357exc:PotomacElectricPowerCompanyMemberus-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 June 30, 2022


☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934


Commission File Number	Name of Registrant; State or Other Jurisdiction of Incorporation; Address of Principal Executive Offices; and Telephone Number	IRS Employer Identification Number

001-16169	EXELON CORPORATION	23-2990190
	(a Pennsylvania corporation) 10 South Dearborn Street P.O. Box 805379 Chicago, Illinois 60680-5379 (800) 483-3220

001-01839	COMMONWEALTH EDISON COMPANY	36-0938600
	(an Illinois corporation) 10 South Dearborn Street Chicago, Illinois 60603-2300 (312) 394-4321

000-16844	PECO ENERGY COMPANY	23-0970240
	(a Pennsylvania corporation) P.O. Box 8699 2301 Market Street Philadelphia, Pennsylvania 19101-8699 (215) 841-4000

001-01910	BALTIMORE GAS AND ELECTRIC COMPANY	52-0280210
	(a Maryland corporation) 2 Center Plaza 110 West Fayette Street Baltimore, Maryland 21201-3708 (410) 234-5000

001-31403	PEPCO HOLDINGS LLC	52-2297449
	(a Delaware limited liability company) 701 Ninth Street, N.W. Washington, District of Columbia 20068-0001 (202) 872-2000

001-01072	POTOMAC ELECTRIC POWER COMPANY	53-0127880
	(a District of Columbia and Virginia corporation) 701 Ninth Street, N.W. Washington, District of Columbia 20068-001 (202) 872-2000

001-01405	DELMARVA POWER & LIGHT COMPANY	51-0084283
	(a Delaware and Virginia corporation) 500 North Wakefield Drive Newark, Delaware 19702-5440 (202) 872-2000

001-03559	ATLANTIC CITY ELECTRIC COMPANY	21-0398280
	(a New Jersey corporation) 500 North Wakefield Drive Newark, Delaware 19702-5440 (202) 872-2000

Securities registered pursuant to Section 12(b) of the Act:

Title of each class

Trading Symbol(s)

Name of each exchange on which registered

EXELON CORPORATION:

Common stock, without par value

EXC

The Nasdaq Stock Market LLC

PECO ENERGY COMPANY:

Trust Receipts of PECO Energy Capital Trust III, each representing a 7.38% Cumulative Preferred Security, Series D, $25 stated value, issued by PECO Energy Capital, L.P. and unconditionally guaranteed by PECO Energy Company

EXC/28

New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes x No o

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes x No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Exelon Corporation

Large Accelerated Filer

Accelerated Filer

☐

Non-accelerated Filer

☐

Smaller Reporting Company

☐

Emerging Growth Company

☐

Commonwealth Edison Company

Large Accelerated Filer

☐

Accelerated Filer

☐

Non-accelerated Filer

Smaller Reporting Company

☐

Emerging Growth Company

☐

PECO Energy Company

Large Accelerated Filer

☐

Accelerated Filer

☐

Non-accelerated Filer

Smaller Reporting Company

☐

Emerging Growth Company

☐

Baltimore Gas and Electric Company

Large Accelerated Filer

☐

Accelerated Filer

☐

Non-accelerated Filer

Smaller Reporting Company

☐

Emerging Growth Company

☐

Pepco Holdings LLC

Large Accelerated Filer

☐

Accelerated Filer

☐

Non-accelerated Filer

Smaller Reporting Company

☐

Emerging Growth Company

☐

Potomac Electric Power Company

Large Accelerated Filer

☐

Accelerated Filer

☐

Non-accelerated Filer

Smaller Reporting Company

☐

Emerging Growth Company

☐

Delmarva Power & Light Company

Large Accelerated Filer

☐

Accelerated Filer

☐

Non-accelerated Filer

Smaller Reporting Company

☐

Emerging Growth Company

☐

Atlantic City Electric Company

Large Accelerated Filer

☐

Accelerated Filer

☐

Non-accelerated Filer

Smaller Reporting Company

☐

Emerging Growth Company

☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes ☐ No x

The number of shares outstanding of each registrant’s common stock as of June 30, 2022 was:


Exelon Corporation Common Stock, without par value			980,472,436
Commonwealth Edison Company Common Stock, $12.50 par value			127,021,391
PECO Energy Company Common Stock, without par value			170,478,507
Baltimore Gas and Electric Company Common Stock, without par value			1,000
Pepco Holdings LLC			not applicable
Potomac Electric Power Company Common Stock, $0.01 par value			100
Delmarva Power & Light Company Common Stock, $2.25 par value			1,000
Atlantic City Electric Company Common Stock, $3.00 par value			8,546,017

TABLE OF CONTENTS


		Page No.
GLOSSARY OF TERMS AND ABBREVIATIONS		4
FILING FORMAT		7
CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING INFORMATION		7
WHERE TO FIND MORE INFORMATION		7
PART I.	FINANCIAL INFORMATION	8
ITEM 1.	FINANCIAL STATEMENTS	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	15
	Consolidated Statements of Cash Flows	16
	Consolidated Balance Sheets	17
	Consolidated Statements of Changes in Shareholders' Equity	19
	PECO Energy Company
	Consolidated Statements of Operations and Comprehensive Income	20
	Consolidated Statements of Cash Flows	21
	Consolidated Balance Sheets	22
	Consolidated Statements of Changes in Shareholder's Equity	24
	Baltimore Gas and Electric Company
	Statements of Operations and Comprehensive Income	25
	Statements of Cash Flows	26
	Balance Sheets	27
	Statements of Changes in Shareholder's Equity	29
	Pepco Holdings LLC
	Consolidated Statements of Operations and Comprehensive Income	30
	Consolidated Statements of Cash Flows	31
	Consolidated Balance Sheets	32
	Consolidated Statements of Changes in Member's Equity	34


						Page No.
			Potomac Electric Power Company
			Statements of Operations and Comprehensive Income			35
			Statements of Cash Flows			36
			Balance Sheets			37
			Statements of Changes in Shareholder's Equity			39
			Delmarva Power & Light Company
			Statements of Operations and Comprehensive Income			40
			Statements of Cash Flows			41
			Balance Sheets			42
			Statements of Changes in Shareholder’s Equity			44
			Atlantic City Electric Company
			Consolidated Statements of Operations and Comprehensive Income			45
			Consolidated Statements of Cash Flows			46
			Consolidated Balance Sheets			47
			Consolidated Statements of Changes in Shareholder’s Equity			49
			Combined Notes to Consolidated Financial Statements
			1. Significant Accounting Policies			50
			2. Discontinued Operations			51
			3. Regulatory Matters			56
			4. Revenue from Contracts with Customers			60
			5. Segment Information			62
			6. Accounts Receivable			71
			7. Income Taxes			74
			8. Retirement Benefits			77
			9. Derivative Financial Instruments			81
			10. Debt and Credit Agreements			83
			11. Fair Value of Financial Assets and Liabilities			86
			12. Commitments and Contingencies			92
			13. Changes in Accumulated Other Comprehensive Income			99

			14. Supplemental Financial Information			100
			15. Related Party Transactions			105


		Page No.


ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	109
	Exelon Corporation	109
	Executive Overview	109
	Financial Results of Operations	109
	Significant 2022 Transactions and Developments	112


	Other Key Business Drivers and Management Strategies	115
	Critical Accounting Policies and Estimates	115
	Results of Operations By Registrant	116
	Commonwealth Edison Company	116
	PECO Energy Company	119
	Baltimore Gas and Electric Company	123
	Pepco Holdings LLC	126
	Potomac Electric Power Company	127
	Delmarva Power & Light Company	130
	Atlantic City Electric Company	134
	Liquidity and Capital Resources	138

ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	146
ITEM 4.	CONTROLS AND PROCEDURES	147
PART II.	OTHER INFORMATION	147
ITEM 1.	LEGAL PROCEEDINGS	147
ITEM 1A.	RISK FACTORS	147
ITEM 4.	MINE SAFETY DISCLOSURES	148
ITEM 5.	OTHER INFORMATION	148
ITEM 6.	EXHIBITS	149
SIGNATURES		152
	Exelon Corporation	152
	Commonwealth Edison Company	153
	PECO Energy Company	154
	Baltimore Gas and Electric Company	155
	Pepco Holdings LLC	156
	Potomac Electric Power Company	157
	Delmarva Power & Light Company	158
	Atlantic City Electric Company	159

Table of Contents


GLOSSARY OF TERMS AND ABBREVIATIONS
Exelon Corporation and Related Entities
Exelon						Exelon Corporation
ComEd						Commonwealth Edison Company
PECO						PECO Energy Company
BGE						Baltimore Gas and Electric Company
Pepco Holdings or PHI						Pepco Holdings LLC
Pepco						Potomac Electric Power Company
DPL						Delmarva Power & Light Company
ACE						Atlantic City Electric Company
Registrants						Exelon, ComEd, PECO, BGE, PHI, Pepco, DPL, and ACE, collectively
Utility Registrants						ComEd, PECO, BGE, Pepco, DPL, and ACE, collectively
ACE Funding or ATF						Atlantic City Electric Transition Funding LLC

BSC						Exelon Business Services Company, LLC
Exelon Corporate						Exelon in its corporate capacity as a holding company
PCI						Potomac Capital Investment Corporation and its subsidiaries
PECO Trust III						PECO Energy Capital Trust III
PECO Trust IV						PECO Energy Capital Trust IV

PHI Corporate						PHI in its corporate capacity as a holding company
PHISCO						PHI Service Company
Former Related Entities
Constellation						Constellation Energy Corporation
Generation						Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC, a subsidiary of Exelon prior to separation on February 1, 2022)

Table of Contents


GLOSSARY OF TERMS AND ABBREVIATIONS
Other Terms and Abbreviations
2021 Form 10-K						The Registrants' Annual Report on Form 10-K for the year ended December 31, 2021 filed with the SEC on February 25, 2022
2021 Recast Form 10-K						The Registrants' Current Report on Form 8-K filed with the SEC on June 30, 2022 to recast Exelon's consolidated financial statements and certain other financial information originally included in the 2021 Form 10-K
Note - of the 2021 Recast Form 10-K						Reference to specific Combined Note to Consolidated Financial Statements in the 2021 Recast Form 10-K
AEC						Alternative Energy Credit that is issued for each megawatt hour of generation from a qualified alternative energy source
AFUDC						Allowance for Funds Used During Construction
AMI						Advanced Metering Infrastructure
AOCI						Accumulated Other Comprehensive Income (Loss)
ARO						Asset Retirement Obligation
BGS						Basic Generation Service
CEJA (formerly Clean Energy Law in the Exelon 2021 Form 10-K)						Climate and Equitable Jobs Act; Illinois Public Act 102-0662 signed into law on September 15, 2021
CERCLA						Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended
CIP						Conservation Incentive Program
CMC						Carbon Mitigation Credit
CODM						Chief Operating Decision Maker(s)
DC PLUG						District of Columbia Power Line Undergrounding Initiative
DCPSC						Public Service Commission of the District of Columbia
DEPSC						Delaware Public Service Commission
DOEE						District of Columbia Department of Energy & Environment
DPP						Deferred Purchase Price
EIMA						Energy Infrastructure Modernization Act (Illinois Senate Bill 1652 and Illinois House Bill 3036)
EPA						United States Environmental Protection Agency
ERCOT						Electric Reliability Council of Texas
ERISA						Employee Retirement Income Security Act of 1974, as amended
ETAC						Energy Transition Assistance Charge
FEJA						Illinois Public Act 99-0906 or Future Energy Jobs Act
FERC						Federal Energy Regulatory Commission
GAAP						Generally Accepted Accounting Principles in the United States
GCR						Gas Cost Rate
GSA						Generation Supply Adjustment
GWh						Gigawatt hour
ICC						Illinois Commerce Commission
Illinois Settlement Legislation						Legislation enacted in 2007 affecting electric utilities in Illinois
IPA						Illinois Power Agency
IRC						Internal Revenue Code
IRS						Internal Revenue Service
LIBOR						London Interbank Offered Rate
MDPSC						Maryland Public Service Commission
MGP						Manufactured Gas Plant
mmcf						Million Cubic Feet

Table of Contents


GLOSSARY OF TERMS AND ABBREVIATIONS
Other Terms and Abbreviations
MW						Megawatt
MWh						Megawatt hour
N/A						Not applicable
NDT						Nuclear Decommissioning Trust
NJBPU						New Jersey Board of Public Utilities
NPNS						Normal Purchase Normal Sale scope exception
NPS						National Park Service
OCI						Other Comprehensive Income
OPEB						Other Postretirement Employee Benefits
PAPUC						Pennsylvania Public Utility Commission
PGC						Purchased Gas Cost Clause
PJM						PJM Interconnection, LLC
POLR						Provider of Last Resort
PPA						Power Purchase Agreement
PP&E						Property, plant, and equipment
PRP						Potentially Responsible Parties
REC						Renewable Energy Credit which is issued for each megawatt hour of generation from a qualified renewable energy source
Regulatory Agreement Units						Nuclear generating units or portions thereof whose decommissioning-related activities are subject to contractual elimination under regulatory accounting
RFP						Request for Proposal
Rider						Reconcilable Surcharge Recovery Mechanism
ROE						Return on equity
ROU						Right-of-use
RPS						Renewable Energy Portfolio Standards
RTO						Regional Transmission Organization
SEC						United States Securities and Exchange Commission
SOFR						Secured Overnight Financing Rate
SOS						Standard Offer Service
STRIDE						Maryland Strategic Infrastructure Development and Enhancement Program
TCJA						Tax Cuts and Jobs Act
Transition Bonds						Transition Bonds issued by ACE Funding
ZEC						Zero Emission Credit or Zero Emission Certificate

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 2021 Form 10-K in Part I, ITEM 1A. Risk 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 (b) Part II, ITEM 8. Financial Statements and Supplementary Data: Note 17, Commitments and Contingencies; (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 (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.

Table of Contents

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

Table of Contents

EXELON CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions, except per share data)	2022		2021		2022		2021
Operating revenues
Electric operating revenues	$	3,934	$	3,739	$	8,415	$	7,609
Natural gas operating revenues	307		234		1,124		867
Revenues from alternative revenue programs	(2)		47		27		176
Total operating revenues	4,239		4,020		9,566		8,652
Operating expenses
Purchased power	1,167		1,006		2,748		2,146
Purchased fuel	107		58		445		276
Purchased power and fuel from affiliates	—		257		159		550
Operating and maintenance	1,109		1,073		2,288		2,155
Depreciation and amortization	830		736		1,647		1,494
Taxes other than income taxes	330		314		684		631
Total operating expenses	3,543		3,444		7,971		7,252

(Loss) gain on sales of assets and businesses	(2)		4		(2)		4


Operating income	694		580		1,593		1,404
Other income and (deductions)
Interest expense, net	(352)		(318)		(684)		(630)
Interest expense to affiliates	(6)		(6)		(13)		(13)
Other, net	175		73		313		131
Total other income and (deductions)	(183)		(251)		(384)		(512)
Income from continuing operations before income taxes	511		329		1,209		892
Income taxes	46		3		263		42
Equity in earnings of unconsolidated affiliates	—		—		—		1
Net income from continuing operations after income taxes	465		326		946		851
Net income (loss) from discontinued operations after income taxes (Note 2)	—		150		117		(640)
Net income	465		476		1,063		211
Net income attributable to noncontrolling interests	—		75		1		99
Net income attributable to common shareholders	$	465	$	401	$	1,062	$	112

Amounts attributable to common shareholders:
Net income from continuing operations	465		326		946		851
Net income (loss) from discontinued operations	—		75		116		(739)
Net income attributable to common shareholders	$	465	$	401	$	1,062	$	112

Comprehensive income, net of income taxes
Net income	$	465	$	476	$	1,063	$	211
Other comprehensive income (loss), net of income taxes
Pension and non-pension postretirement benefit plans:
Prior service benefit reclassified to periodic benefit cost	2		(1)		2		(2)
Actuarial loss reclassified to periodic benefit cost	10		56		24		112
Pension and non-pension postretirement benefit plan valuation adjustment	—		—		—		(2)


Unrealized gain on foreign currency translation	—		2		—		3

Other comprehensive income	12		57		26		111
Comprehensive income	477		533		1,089		322
Comprehensive income attributable to noncontrolling interests	—		75		1		99
Comprehensive income attributable to common shareholders	$	477	$	458	$	1,088	$	223

Average shares of common stock outstanding:
Basic	981		978		981		978
Assumed exercise and/or distributions of stock-based awards	1		1		1		1
Diluted(a)	982		979		982		979

Earnings per average common share from continuing operations
Basic	$	0.47	$	0.33	$	0.96	$	0.87
Diluted	$	0.47	$	0.33	$	0.96	$	0.87

Earnings (losses) per average common share from discontinued operations
Basic	$	—	$	0.08	$	0.12	$	(0.76)
Diluted	$	—	$	0.08	$	0.12	$	(0.76)

__________

(a)The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect were none for the three and six months ended June 30, 2022 and 2021, respectively.

See the Combined Notes to Consolidated Financial Statements

Table of Contents

EXELON CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Six Months Ended June 30,
(In millions)	2022		2021
Cash flows from operating activities
Net income	$	1,063	$	211
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	1,854		4,180
Asset impairments	—		500

Gain on sales of assets and businesses	(8)		(83)

Deferred income taxes and amortization of investment tax credits	143		(163)
Net fair value changes related to derivatives	(59)		(490)
Net realized and unrealized losses (gains) on NDT funds	205		(376)
Net unrealized losses (gains) on equity investments	16		(96)
Other non-cash operating activities	276		(331)
Changes in assets and liabilities:
Accounts receivable	(795)		(16)
Inventories	12		1
Accounts payable and accrued expenses	544		(87)
Option premiums (paid) received, net	(39)		2
Collateral received, net	1,689		957
Income taxes	23		190
Regulatory assets and liabilities, net	(376)		(276)
Pension and non-pension postretirement benefit contributions	(585)		(559)
Other assets and liabilities	(723)		(2,426)
Net cash flows provided by operating activities	3,240		1,138
Cash flows from investing activities
Capital expenditures	(3,507)		(4,040)
Proceeds from NDT fund sales	488		4,438
Investment in NDT funds	(516)		(4,538)
Collection of DPP	169		2,209


Proceeds from sales of assets and businesses	16		724


Other investing activities	4		17
Net cash flows used in investing activities	(3,346)		(1,190)
Cash flows from financing activities
Changes in short-term borrowings	(597)		(666)
Proceeds from short-term borrowings with maturities greater than 90 days	1,150		500
Repayments on short-term borrowings with maturities greater than 90 days	(350)		—
Issuance of long-term debt	5,151		2,455
Retirement of long-term debt	(1,707)		(630)





Dividends paid on common stock	(663)		(747)

Proceeds from employee stock plans	17		47
Transfer of cash, restricted cash, and cash equivalents to Constellation	(2,594)		—
Other financing activities	(84)		(64)
Net cash flows provided by financing activities	323		895
Increase in cash, restricted cash, and cash equivalents	217		843
Cash, restricted cash, and cash equivalents at beginning of period	1,619		1,166
Cash, restricted cash, and cash equivalents at end of period	$	1,836	$	2,009

Supplemental cash flow information
Decrease in capital expenditures not paid	$	(276)	$	(313)
Increase in DPP	348		1,958
(Decrease) increase in PP&E related to ARO update	(335)		2

See the Combined Notes to Consolidated Financial Statements

Table of Contents

EXELON CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	816	$	672
Restricted cash and cash equivalents	961		321

Accounts receivable
Customer accounts receivable	2,219		2,189
Customer allowance for credit losses	(354)		(320)
Customer accounts receivable, net	1,865		1,869
Other accounts receivable	1,403		1,068
Other allowance for credit losses	(81)		(72)
Other accounts receivable, net	1,322		996
Inventories, net
Fossil fuel	133		105
Materials and supplies	491		476
Regulatory assets	1,239		1,296
Other	515		387
Current assets of discontinued operations	—		7,835
Total current assets	7,342		13,957
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 assets
Regulatory assets	8,350		8,224
Goodwill	6,630		6,630
Receivable related to Regulatory Agreement Units	2,265		—
Investments	235		250
Other	1,017		885
Property, plant, and equipment, deferred debits, and other assets of discontinued operations	—		38,509
Total deferred debits and other assets	18,497		54,498
Total assets	$	92,295	$	133,013

See the Combined Notes to Consolidated Financial Statements

Table of Contents

EXELON CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities
Short-term borrowings	$	2,003	$	1,248
Long-term debt due within one year	505		2,153
Accounts payable	2,451		2,379
Accrued expenses	1,057		1,137
Payables to affiliates	5		5
Regulatory liabilities	411		376
Mark-to-market derivative liabilities	—		18
Unamortized energy contract liabilities	11		89
Other	1,588		766
Current liabilities of discontinued operations	—		7,940
Total current liabilities	8,031		16,111
Long-term debt	35,789		30,749
Long-term debt to financing trusts	390		390
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	11,240		10,611
Regulatory liabilities	8,513		9,628
Pension obligations	1,406		2,051
Non-pension postretirement benefit obligations	800		811
Asset retirement obligations	275		271
Mark-to-market derivative liabilities	103		201
Unamortized energy contract liabilities	38		146

Other	2,054		1,573
Long-term debt, deferred credits, and other liabilities of discontinued operations	—		25,676
Total deferred credits and other liabilities	24,429		50,968
Total liabilities	68,639		98,218
Commitments and contingencies	0		0

Shareholders’ equity
Common stock (No par value, 2,000 shares authorized, 980 shares and 979 shares outstanding at June 30, 2022 and December 31, 2021, respectively)	20,319		20,324
Treasury stock, at cost (2 shares at June 30, 2022 and December 31, 2021)	(123)		(123)
Retained earnings	4,161		16,942
Accumulated other comprehensive loss, net	(701)		(2,750)
Total shareholders’ equity	23,656		34,393
Noncontrolling interests	—		402
Total equity	23,656		34,795
Total liabilities and shareholders’ equity	$	92,295	$	133,013

See the Combined Notes to Consolidated Financial Statements

Table of Contents

EXELON CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY

(Unaudited)


	Six Months Ended June 30, 2022
(In millions, shares in thousands)	Issued Shares	Common Stock		Treasury Stock		Retained Earnings		Accumulated Other Comprehensive Loss, net		Noncontrolling Interests		Total Shareholders' Equity
Balance, December 31, 2021	981,291	$	20,324	$	(123)	$	16,942	$	(2,750)	$	402	$	34,795
Net income	—	—		—		597		—		1		598
Long-term incentive plan activity	540	(13)		—		—		—		—		(13)
Employee stock purchase plan issuances	211	9		—		—		—		—		9


Changes in equity of noncontrolling interests	—	—		—		—		—		(7)		(7)

Distribution of Constellation (Note 2)	—	(21)		—		(13,179)		2,023		(396)		(11,573)
Common stock dividends ($0.34/common share)	—	—		—		(332)		—		—		(332)
Other comprehensive income, net of income taxes	—	—		—		—		14		—		14

Balance, March 31, 2022	982,042	$	20,299	$	(123)	$	4,028	$	(713)	$	—	$	23,491
Net income	—	—		—		465		—		—		465
Long-term incentive plan activity	21	10		—		—		—		—		10
Employee stock purchase plan issuances	242	10		—		—		—		—		10

Changes in equity of noncontrolling interests	—	—		—		—		—		—		—


Common stock dividends ($0.34/common share)	—	—		—		(332)		—		—		(332)
Other comprehensive income, net of income taxes	—	—		—		—		12		—		12

Balance, June 30, 2022	982,305	$	20,319	$	(123)	$	4,161	$	(701)	$	—	$	23,656

See the Combined Notes to Consolidated Financial Statements

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, 2020	977,466	$	19,373	$	(123)	$	16,735	$	(3,400)	$	2,283	$	34,868
Net (loss) income	—	—		—		(289)		—		25		(264)
Long-term incentive plan activity	640	5		—		—		—		—		5
Employee stock purchase plan issuances	902	34		—		—		—		—		34


Changes in equity of noncontrolling interests	—	—		—		—		—		(10)		(10)

Common stock dividends ($0.38/common share)	—	—		—		(374)		—		—		(374)
Other comprehensive income, net of income taxes	—	—		—		—		54		—		54

Balance, March 31, 2021	979,008	$	19,412	$	(123)	$	16,072	$	(3,346)	$	2,298	$	34,313
Net income	—	—		—		401		—		75		476
Long-term incentive plan activity	237	24		—		—		—		—		24
Employee stock purchase plan issuances	420	18		—		—		—		—		18

Changes in equity of noncontrolling interests	—	—		—		—		—		(13)		(13)

Common stock dividends ($0.38/common share)	—	—		—		(375)		—		—		(375)
Other comprehensive income, net of income taxes	—	—		—		—		57		—		57
Balance, June 30, 2021	979,665	$	19,454	$	(123)	$	16,098	$	(3,289)	$	2,360	$	34,500

See the Combined Notes to Consolidated Financial Statements

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)	2022		2021		2022		2021
Operating revenues
Electric operating revenues	$	1,387	$	1,503	$	3,075	$	2,977
Revenues from alternative revenue programs	35		9		75		64
Operating revenues from affiliates	3		5		8		11
Total operating revenues	1,425		1,517		3,158		3,052
Operating expenses
Purchased power	283		421		862		862
Purchased power from affiliate	—		79		59		163
Operating and maintenance	258		250		523		495
Operating and maintenance from affiliates	80		73		166		144
Depreciation and amortization	328		296		649		589
Taxes other than income taxes	90		77		185		153
Total operating expenses	1,039		1,196		2,444		2,406
Loss on sales of assets	(2)		—		(2)		—
Operating income	384		321		712		646
Other income and (deductions)
Interest expense, net	(101)		(95)		(197)		(187)
Interest expense to affiliates	(3)		(3)		(7)		(6)
Other, net	13		15		26		22
Total other income and (deductions)	(91)		(83)		(178)		(171)
Income before income taxes	293		238		534		475
Income taxes	66		46		119		85
Net income	$	227	$	192	$	415	$	390
Comprehensive income	$	227	$	192	$	415	$	390

See the Combined Notes to Consolidated Financial Statements

Table of Contents

COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Six Months Ended June 30,
(In millions)	2022		2021
Cash flows from operating activities
Net income	$	415	$	390
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	649		589

Deferred income taxes and amortization of investment tax credits	122		143

Other non-cash operating activities	(18)		23
Changes in assets and liabilities:
Accounts receivable	(163)		(48)
Receivables from and payables to affiliates, net	(43)		5
Inventories	(2)		(2)
Accounts payable and accrued expenses	123		(45)
Collateral received, net	60		2
Income taxes	(19)		(34)
Regulatory assets and liabilities, net	(267)		(181)
Pension and non-pension postretirement benefit contributions	(178)		(173)
Other assets and liabilities	(91)		(111)
Net cash flows provided by operating activities	588		558
Cash flows from investing activities
Capital expenditures	(1,208)		(1,162)




Other investing activities	15		12
Net cash flows used in investing activities	(1,193)		(1,150)
Cash flows from financing activities
Changes in short-term borrowings	—		(290)
Issuance of long-term debt	750		700


Dividends paid on common stock	(289)		(253)
Contributions from parent	335		395


Other financing activities	(12)		(11)
Net cash flows provided by financing activities	784		541
Increase (decrease) in cash, restricted cash, and cash equivalents	179		(51)
Cash, restricted cash, and cash equivalents at beginning of period	384		405
Cash, restricted cash, and cash equivalents at end of period	$	563	$	354

Supplemental cash flow information
Decrease in capital expenditures not paid	$	(44)	$	(93)

See the Combined Notes to Consolidated Financial Statements

Table of Contents

COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	120	$	131
Restricted cash and cash equivalents	384		210
Accounts receivable
Customer accounts receivable	589		647
Customer allowance for credit losses	(81)		(73)
Customer accounts receivable, net	508		574
Other accounts receivable	448		227
Other allowance for credit losses	(18)		(17)
Other accounts receivable, net	430		210

Receivables from affiliates	3		16


Inventories, net	171		170

Regulatory assets	325		335

Other	143		76
Total current assets	2,084		1,722
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 assets
Regulatory assets	2,134		1,870

Goodwill	2,625		2,625
Receivables from affiliates	—		2,761
Receivable related to Regulatory Agreement Units	1,973		—
Investments	6		6
Prepaid pension asset	1,232		1,086


Other	467		405
Total deferred debits and other assets	8,437		8,753
Total assets	$	37,194	$	36,470

See the Combined Notes to Consolidated Financial Statements

Table of Contents

COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities


Accounts payable	$	756	$	647
Accrued expenses	345		384
Payables to affiliates	65		121

Customer deposits	99		99
Regulatory liabilities	216		185
Mark-to-market derivative liabilities	—		18

Other	253		133
Total current liabilities	1,734		1,587
Long-term debt	10,516		9,773
Long-term debt to financing trust	205		205
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	4,852		4,685
Regulatory liabilities	6,111		6,759
Asset retirement obligations	145		144

Non-pension postretirement benefits obligations	168		169

Mark-to-market derivative liabilities	103		201


Other	544		592
Total deferred credits and other liabilities	11,923		12,550
Total liabilities	24,378		24,115
Commitments and contingencies	0		0
Shareholders’ equity
Common stock	1,588		1,588


Other paid-in capital	9,411		9,076
Retained earnings	1,817		1,691

Total shareholders’ equity	12,816		12,355
Total liabilities and shareholders’ equity	$	37,194	$	36,470

See the Combined Notes to Consolidated Financial Statements

Table of Contents

COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY

(Unaudited)


	Six Months Ended June 30, 2022
(In millions)	Common Stock		Other Paid-In Capital		Retained Earnings		Total Shareholders’ Equity
Balance, December 31, 2021	$	1,588	$	9,076	$	1,691	$	12,355
Net income	—		—		188		188
Common stock dividends	—		—		(144)		(144)
Contributions from parent	—		167		—		167
Balance, March 31, 2022	$	1,588	$	9,243	$	1,735	$	12,566
Net income	—		—		227		227
Common stock dividends	—		—		(145)		(145)
Contributions from parent	—		168		—		168
Balance, June 30, 2022	$	1,588	$	9,411	$	1,817	$	12,816





	Six Months Ended June 30, 2021
(In millions)	Common Stock		Other Paid-In Capital		Retained Earnings		Total Shareholders’ Equity
Balance, December 31, 2020	$	1,588	$	8,285	$	1,456	$	11,329
Net income	—		—		197		197
Common stock dividends	—		—		(127)		(127)
Contributions from parent	—		198		—		198
Balance, March 31, 2021	$	1,588	$	8,483	$	1,526	$	11,597
Net income	—		—		192		192
Common stock dividends	—		—		(126)		(126)
Contributions from parent	—		197		—		197
Balance, June 30, 2021	$	1,588	$	8,680	$	1,592	$	11,860

See the Combined Notes to Consolidated Financial Statements

Table of Contents

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2022		2021		2022		2021
Operating revenues
Electric operating revenues	$	707	$	602	$	1,441	$	1,251
Natural gas operating revenues	108		82		414		310
Revenues from alternative revenue programs	—		7		6		17
Operating revenues from affiliates	1		2		2		4
Total operating revenues	816		693		1,863		1,582
Operating expenses
Purchased power	244		145		472		334
Purchased fuel	39		22		184		108
Purchased power from affiliate	—		40		33		81
Operating and maintenance	168		166		364		360
Operating and maintenance from affiliates	47		43		99		83
Depreciation and amortization	93		87		185		173
Taxes other than income taxes	48		49		95		92
Total operating expenses	639		552		1,432		1,231

Operating income	177		141		431		351
Other income and (deductions)
Interest expense, net	(40)		(39)		(78)		(74)
Interest expense to affiliates	(3)		(3)		(6)		(6)
Other, net	8		7		16		12
Total other income and (deductions)	(35)		(35)		(68)		(68)
Income before income taxes	142		106		363		283
Income taxes	9		2		24		12

Net income	$	133	$	104	$	339	$	271
Comprehensive income	$	133	$	104	$	339	$	271

See the Combined Notes to Consolidated Financial Statements

Table of Contents

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Six Months Ended June 30,
(In millions)	2022		2021
Cash flows from operating activities
Net income	$	339	$	271
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	185		173


Deferred income taxes and amortization of investment tax credits	14		21
Other non-cash operating activities	4		(5)
Changes in assets and liabilities:
Accounts receivable	(29)		86
Receivables from and payables to affiliates, net	(40)		2
Inventories	(8)		3
Accounts payable and accrued expenses	5		(46)

Income taxes	49		24
Regulatory assets and liabilities, net	(24)		(14)
Pension and non-pension postretirement benefit contributions	(13)		(15)
Other assets and liabilities	(70)		(126)
Net cash flows provided by operating activities	412		374
Cash flows from investing activities
Capital expenditures	(658)		(577)


Other investing activities	5		4
Net cash flows used in investing activities	(653)		(573)
Cash flows from financing activities

Changes in short-term borrowings	210		—
Issuance of long-term debt	350		375
Retirement of long-term debt	(350)		—

Changes in Exelon intercompany money pool	—		(40)
Dividends paid on common stock	(200)		(169)
Contributions from parent	227		395


Other financing activities	(8)		(4)
Net cash flows provided by financing activities	229		557
(Decrease) increase in cash, restricted cash, and cash equivalents	(12)		358
Cash, restricted cash, and cash equivalents at beginning of period	44		26
Cash, restricted cash, and cash equivalents at end of period	$	32	$	384

Supplemental cash flow information
Decrease in capital expenditures not paid	$	(11)	$	(16)

See the Combined Notes to Consolidated Financial Statements

Table of Contents

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	23	$	36
Restricted cash and cash equivalents	9		8
Accounts receivable
Customer accounts receivable	493		489
Customer allowance for credit losses	(107)		(105)
Customer accounts receivable, net	386		384
Other accounts receivable	138		116
Other allowance for credit losses	(10)		(7)
Other accounts receivable, net	128		109

Receivables from affiliates	—		1


Inventories, net
Fossil fuel	55		51
Materials and supplies	48		45
Prepaid utility taxes	85		1
Regulatory assets	61		48

Other	36		28
Total current assets	831		711
Property, plant, and equipment (net of accumulated depreciation and amortization of $4,021 and $3,964 as of June 30, 2022 and December 31, 2021, respectively)	11,591		11,117
Deferred debits and other assets
Regulatory assets	1,033		943



Receivables from affiliates	—		597
Receivable related to Regulatory Agreement Units	292		—
Investments	32		34
Prepaid pension asset	405		386


Other	32		36
Total deferred debits and other assets	1,794		1,996
Total assets	$	14,216	$	13,824

See the Combined Notes to Consolidated Financial Statements

Table of Contents

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities
Short-term borrowings	$	210	$	—
Long-term debt due within one year	50		350
Accounts payable	525		494
Accrued expenses	161		136
Payables to affiliates	29		70

Customer deposits	53		48
Regulatory liabilities	75		94


Other	47		35
Total current liabilities	1,150		1,227
Long-term debt	4,142		3,847
Long-term debt to financing trusts	184		184
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	2,534		2,421
Regulatory liabilities	329		635
Asset retirement obligations	29		29
Non-pension postretirement benefits obligations	288		286





Other	82		83
Total deferred credits and other liabilities	3,262		3,454
Total liabilities	8,738		8,712
Commitments and contingencies	0		0
Shareholder’s equity
Common stock	3,655		3,428


Retained earnings	1,823		1,684


Total shareholder’s equity	5,478		5,112
Total liabilities and shareholder's equity	$	14,216	$	13,824

See the Combined Notes to Consolidated Financial Statements

Table of Contents

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY

(Unaudited)


	Six Months Ended June 30, 2022
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2021	$	3,428	$	1,684	$	5,112
Net income	—		206		206
Common stock dividends	—		(100)		(100)
Contributions from parent	227		—		227
Balance, March 31, 2022	$	3,655	$	1,790	$	5,445
Net income	—		133		133
Common stock dividends	—		(100)		(100)

Balance, June 30, 2022	$	3,655	$	1,823	$	5,478





	Six Months Ended June 30, 2021
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2020	$	3,014	$	1,519	$	4,533
Net income	—		167		167
Common stock dividends	—		(85)		(85)

Balance, March 31, 2021	$	3,014	$	1,601	$	4,615
Net income	—		104		104
Common stock dividends	—		(84)		(84)
Contributions from parent	395		—		395
Balance, June 30, 2021	$	3,409	$	1,621	$	5,030

See the Combined Notes to Consolidated Financial Statements

Table of Contents

BALTIMORE GAS AND ELECTRIC COMPANY

STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2022		2021		2022		2021
Operating revenues
Electric operating revenues	$	642	$	560	$	1,377	$	1,180
Natural gas operating revenues	161		125		585		455
Revenues from alternative revenue programs	(20)		(10)		(32)		8
Operating revenues from affiliates	3		7		10		13
Total operating revenues	786		682		1,940		1,656
Operating expenses
Purchased power	241		133		526		295
Purchased fuel	48		27		199		126
Purchased power and fuel from affiliate	—		59		18		129
Operating and maintenance	154		147		321		299
Operating and maintenance from affiliates	51		46		102		91
Depreciation and amortization	152		141		322		293
Taxes other than income taxes	71		67		148		139
Total operating expenses	717		620		1,636		1,372

Operating income	69		62		304		284
Other income and (deductions)
Interest expense, net	(36)		(34)		(71)		(67)

Other, net	5		9		11		16
Total other income and (deductions)	(31)		(25)		(60)		(51)
Income before income taxes	38		37		244		233
Income taxes	1		(8)		10		(21)

Net income	$	37	$	45	$	234	$	254



Comprehensive income	$	37	$	45	$	234	$	254

See the Combined Notes to Consolidated Financial Statements

Table of Contents

BALTIMORE GAS AND ELECTRIC COMPANY

STATEMENTS OF CASH FLOWS

(Unaudited)


	Six Months Ended June 30,
(In millions)	2022		2021
Cash flows from operating activities
Net income	$	234	$	254
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	322		293

Deferred income taxes and amortization of investment tax credits	13		11

Other non-cash operating activities	79		28
Changes in assets and liabilities:
Accounts receivable	(14)		73
Receivables from and payables to affiliates, net	(11)		(19)
Inventories	(27)		(9)
Accounts payable and accrued expenses	(12)		(51)
Collateral received, net	190		2
Income taxes	(27)		(27)
Regulatory assets and liabilities, net	(36)		(61)
Pension and non-pension postretirement benefit contributions	(59)		(71)
Other assets and liabilities	24		(35)
Net cash flows provided by operating activities	676		388
Cash flows from investing activities
Capital expenditures	(578)		(620)

Other investing activities	7		10
Net cash flows used in investing activities	(571)		(610)
Cash flows from financing activities
Changes in short-term borrowings	(130)		—
Issuance of long-term debt	500		600





Dividends paid on common stock	(150)		(146)
Contributions from parent	186		—
Other financing activities	(7)		(6)
Net cash flows provided by financing activities	399		448
Increase in cash, restricted cash, and cash equivalents	504		226
Cash, restricted cash, and cash equivalents at beginning of period	55		145
Cash, restricted cash, and cash equivalents at end of period	$	559	$	371

Supplemental cash flow information
Decrease in capital expenditures not paid	$	(21)	$	(71)

See the Combined Notes to Consolidated Financial Statements

Table of Contents

BALTIMORE GAS AND ELECTRIC COMPANY

BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	354	$	51
Restricted cash and cash equivalents	205		4
Accounts receivable
Customer accounts receivable	462		436
Customer allowance for credit losses	(57)		(38)
Customer accounts receivable, net	405		398
Other accounts receivable	122		124
Other allowance for credit losses	(11)		(9)
Other accounts receivable, net	111		115

Receivables from affiliates	—		1



Inventories, net
Fossil fuel	68		42
Materials and supplies	54		53
Prepaid utility taxes	—		49
Regulatory assets	178		215

Other	10		8
Total current assets	1,385		936
Property, plant, and equipment (net of accumulated depreciation and amortization of $4,464 and $4,299 as of June 30, 2022 and December 31, 2021, respectively)	10,899		10,577
Deferred debits and other assets
Regulatory assets	465		477

Investments	7		14



Prepaid pension asset	307		276


Other	30		44
Total deferred debits and other assets	809		811
Total assets	$	13,093	$	12,324

See the Combined Notes to Consolidated Financial Statements

Table of Contents

BALTIMORE GAS AND ELECTRIC COMPANY

BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities
Short-term borrowings	$	—	$	130
Long-term debt due within one year	250		250
Accounts payable	339		349
Accrued expenses	133		176
Payables to affiliates	30		48

Customer deposits	100		97
Regulatory liabilities	45		26


Other	224		48
Total current liabilities	1,121		1,124
Long-term debt	4,206		3,711

Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	1,777		1,686
Regulatory liabilities	869		934
Asset retirement obligations	26		26
Non-pension postretirement benefits obligations	169		175





Other	85		98
Total deferred credits and other liabilities	2,926		2,919
Total liabilities	8,253		7,754
Commitments and contingencies	0		0
Shareholder's equity
Common stock	2,761		2,575


Retained earnings	2,079		1,995


Total shareholder's equity	4,840		4,570


Total liabilities and shareholder's equity	$	13,093	$	12,324

See the Combined Notes to Consolidated Financial Statements

Table of Contents

BALTIMORE GAS AND ELECTRIC COMPANY

STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY

(Unaudited)


	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 parent	186		—		186




Balance, June 30, 2022	$	2,761	$	2,079	$	4,840

	Six Months Ended June 30, 2021
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2020	$	2,318	$	1,879	$	4,197
Net income	—		209		209
Common stock dividends	—		(74)		(74)
Balance, March 31, 2021	$	2,318	$	2,014	$	4,332
Net income	—		45		45
Common stock dividends	—		(72)		(72)

Balance, June 30, 2021	$	2,318	$	1,987	$	4,305

See the Combined Notes to Consolidated Financial Statements

Table of Contents

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2022		2021		2022		2021
Operating revenues
Electric operating revenues	$	1,199	$	1,071	$	2,522	$	2,195
Natural gas operating revenues	37		24		120		94
Revenues from alternative revenue programs	(17)		41		(22)		88
Operating revenues from affiliates	2		4		6		7
Total operating revenues	1,221		1,140		2,626		2,384
Operating expenses
Purchased power	401		308		888		656
Purchased fuel	19		9		61		41
Purchased power from affiliates	—		79		50		177
Operating and maintenance	245		217		493		434
Operating and maintenance from affiliates	47		39		98		79
Depreciation and amortization	240		194		459		404
Taxes other than income taxes	114		109		233		222
Total operating expenses	1,066		955		2,282		2,013


Operating income	155		185		344		371
Other income and (deductions)
Interest expense, net	(73)		(67)		(143)		(134)

Other, net	19		20		37		36
Total other income and (deductions)	(54)		(47)		(106)		(98)
Income before income taxes	101		138		238		273
Income taxes	1		(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

Table of Contents

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Six Months Ended June 30,
(In millions)	2022		2021
Cash flows from operating activities
Net income	$	230	$	269

Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	459		404


Deferred income taxes and amortization of investment tax credits	(7)		10

Other non-cash operating activities	76		(50)
Changes in assets and liabilities:
Accounts receivable	(92)		(30)
Receivables from and payables to affiliates, net	(53)		(22)
Inventories	(7)		3
Accounts payable and accrued expenses	10		(35)

Collateral received, net	403		—
Income taxes	(2)		(1)
Regulatory assets and liabilities, net	(71)		(33)
Pension and non-pension postretirement benefit contributions	(70)		(40)
Other assets and liabilities	(86)		(98)
Net cash flows provided by operating activities	790		377
Cash flows from investing activities
Capital expenditures	(776)		(889)




Other investing activities	3		(2)
Net cash flows used in investing activities	(773)		(891)
Cash flows from financing activities
Changes in short-term borrowings	(425)		(36)


Issuance of long-term debt	700		625
Retirement of long-term debt	(200)		(249)
Changes in Exelon intercompany money pool	17		(12)



Distributions to member	(395)		(414)
Contributions from member	704		560


Other financing activities	(12)		(8)
Net cash flows provided by financing activities	389		466
Increase (decrease) in cash, restricted cash, and cash equivalents	406		(48)
Cash, restricted cash, and cash equivalents at beginning of period	213		160
Cash, restricted cash, and cash equivalents at end of period	$	619	$	112

Supplemental cash flow information
Decrease in capital expenditures not paid	$	(48)	$	(41)

See the Combined Notes to Consolidated Financial Statements

Table of Contents

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	278	$	136
Restricted cash and cash equivalents	341		77
Accounts receivable
Customer accounts receivable	676		616
Customer allowance for credit losses	(109)		(104)
Customer accounts receivable, net	567		512
Other accounts receivable	291		283
Other allowance for credit losses	(42)		(39)
Other accounts receivable, net	249		244

Receivables from affiliates	1		2


Inventories, net
Fossil fuel	10		11
Materials and supplies	217		209


Regulatory assets	435		432

Other	90		69
Total current assets	2,188		1,692
Property, plant, and equipment (net of accumulated depreciation and amortization of $2,365 and $2,108 as of June 30, 2022 and December 31, 2021, respectively)	16,915		16,498
Deferred debits and other assets
Regulatory assets	1,714		1,794
Goodwill	4,005		4,005
Investments	139		145


Prepaid pension asset	380		344

Deferred income taxes	6		8
Other	245		258
Total deferred debits and other assets	6,489		6,554
Total assets	$	25,592	$	24,744

See the Combined Notes to Consolidated Financial Statements

Table of Contents

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
LIABILITIES AND MEMBER'S EQUITY
Current liabilities
Short-term borrowings	$	43	$	468
Long-term debt due within one year	200		399
Accounts payable	574		578
Accrued expenses	246		281
Payables to affiliates	50		104
Borrowings from Exelon intercompany money pool	24		7

Customer deposits	81		81
Regulatory liabilities	71		68
Unamortized energy contract liabilities	11		89

PPA termination obligation	87		—
Other	580		171
Total current liabilities	1,967		2,246
Long-term debt	7,827		7,148
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	2,752		2,675
Regulatory liabilities	1,142		1,238
Asset retirement obligations	70		70
Non-pension postretirement benefit obligations	57		66




Unamortized energy contract liabilities	38		146
Other	615		570
Total deferred credits and other liabilities	4,674		4,765
Total liabilities	14,468		14,159
Commitments and contingencies	0		0

Member's equity
Membership interest	11,499		10,795

Undistributed losses	(375)		(210)

Total member's equity	11,124		10,585
Total liabilities and member's equity	$	25,592	$	24,744

See the Combined Notes to Consolidated Financial Statements

Table of Contents

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY

(Unaudited)


	Six Months Ended June 30, 2022
(In millions)	Membership Interest		Undistributed (Losses)/Earnings		Total Member's Equity
Balance, December 31, 2021	$	10,795	$	(210)	$	10,585
Net income	—		130		130
Distributions to member	—		(102)		(102)
Contributions from member	704		—		704
Balance, March 31, 2022	$	11,499	$	(182)	$	11,317
Net income	—		100		100
Distributions to member	—		(293)		(293)

Balance, June 30, 2022	$	11,499	$	(375)	$	11,124


	Six Months Ended June 30, 2021
(In millions)	Membership Interest		Undistributed (Losses)/Earnings		Total Member's Equity
Balance, December 31, 2020	$	10,112	$	(68)	$	10,044
Net income	—		128		128
Distributions to member	—		(81)		(81)
Contributions from member	560		—		560
Balance, March 31, 2021	$	10,672	$	(21)	$	10,651
Net income	—		141		141
Distributions to member	—		(333)		(333)

Balance, June 30, 2021	$	10,672	$	(213)	$	10,459

See the Combined Notes to Consolidated Financial Statements

Table of Contents

POTOMAC ELECTRIC POWER COMPANY

STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2022		2021		2022		2021
Operating revenues
Electric operating revenues	$	580	$	503	$	1,200	$	1,027
Revenues from alternative revenue programs	(1)		19		(7)		46
Operating revenues from affiliates	2		1		2		3
Total operating revenues	581		523		1,195		1,076
Operating expenses
Purchased power	162		76		336		168
Purchased power from affiliate	—		57		39		130
Operating and maintenance	72		62		145		118
Operating and maintenance from affiliates	56		51		115		103
Depreciation and amortization	105		96		213		199
Taxes other than income taxes	92		87		186		177
Total operating expenses	487		429		1,034		895



Operating income	94		94		161		181
Other income and (deductions)
Interest expense, net	(38)		(35)		(74)		(69)

Other, net	13		13		26		25
Total other income and (deductions)	(25)		(22)		(48)		(44)
Income before income taxes	69		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

Table of Contents

POTOMAC ELECTRIC POWER COMPANY

STATEMENTS OF CASH FLOWS

(Unaudited)


	Six Months Ended June 30,
(In millions)	2022		2021
Cash flows from operating activities
Net income	$	116	$	134
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	213		199

Deferred income taxes and amortization of investment tax credits	(7)		10

Other non-cash operating activities	17		(43)
Changes in assets and liabilities:
Accounts receivable	(62)		(23)
Receivables from and payables to affiliates, net	(39)		(11)
Inventories	(6)		1
Accounts payable and accrued expenses	6		(26)
Collateral received, net	85		—
Income taxes	(24)		(20)
Regulatory assets and liabilities, net	(36)		(38)
Pension and non-pension postretirement benefit contributions	(7)		(7)
Other assets and liabilities	(15)		(41)
Net cash flows provided by operating activities	241		135
Cash flows from investing activities
Capital expenditures	(402)		(439)




Other investing activities	2		(2)
Net cash flows used in investing activities	(400)		(441)
Cash flows from financing activities
Changes in short-term borrowings	(132)		119
Issuance of long-term debt	400		150
Retirement of long-term debt	(200)		—
Changes in PHI intercompany money pool	73		9
Dividends paid on common stock	(300)		(123)
Contributions from parent	387		138


Other financing activities	(6)		(2)
Net cash flows provided by financing activities	222		291
Increase (decrease) in cash, restricted cash, and cash equivalents	63		(15)
Cash, restricted cash, and cash equivalents at beginning of period	68		65
Cash, restricted cash, and cash equivalents at end of period	$	131	$	50

Supplemental cash flow information
Decrease in capital expenditures not paid	$	(24)	$	(15)

See the Combined Notes to Consolidated Financial Statements

Table of Contents

POTOMAC ELECTRIC POWER COMPANY

BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	14	$	34
Restricted cash and cash equivalents	117		34
Accounts receivable
Customer accounts receivable	328		277
Customer allowance for credit losses	(42)		(37)
Customer accounts receivable, net	286		240
Other accounts receivable	165		160
Other allowance for credit losses	(20)		(16)
Other accounts receivable, net	145		144

Receivables from affiliates	9		—


Inventories, net	125		119



Regulatory assets	220		213

Other	12		25
Total current assets	928		809
Property, plant, and equipment (net of accumulated depreciation and amortization of $3,970 and $3,875 as of June 30, 2022 and December 31, 2021, respectively)	8,365		8,104
Deferred debits and other assets
Regulatory assets	478		532
Investments	118		120



Prepaid pension asset	277		279

Other	60		59
Total deferred debits and other assets	933		990
Total assets	$	10,226	$	9,903

See the Combined Notes to Consolidated Financial Statements

Table of Contents

POTOMAC ELECTRIC POWER COMPANY

BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities
Short-term borrowings	$	43	$	175
Long-term debt due within one year	114		313
Accounts payable	269		272
Accrued expenses	124		160
Payables to affiliates	29		59


Borrowings from PHI intercompany money pool	73		—
Customer deposits	36		35
Regulatory liabilities	12		14
Merger related obligation	25		27

Other	149		55
Total current liabilities	874		1,110
Long-term debt	3,528		3,132

Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	1,314		1,275
Regulatory liabilities	507		549
Asset retirement obligations	45		45

Non-pension postretirement benefit obligations	—		3




Other	280		314
Total deferred credits and other liabilities	2,146		2,186
Total liabilities	6,548		6,428
Commitments and contingencies	0		0
Shareholder's equity
Common stock	2,689		2,302


Retained earnings	989		1,173

Total shareholder's equity	3,678		3,475
Total liabilities and shareholder's equity	$	10,226	$	9,903

See the Combined Notes to Consolidated Financial Statements

Table of Contents

POTOMAC ELECTRIC POWER COMPANY

STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY

(Unaudited)


	Six Months Ended June 30, 2022
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2021	$	2,302	$	1,173	$	3,475
Net income	—		46		46
Common stock dividends	—		(42)		(42)
Contributions from parent	387		—		387
Balance, March 31, 2022	$	2,689	$	1,177	$	3,866
Net income	—		70		70



Common stock dividends	—		(258)		(258)

Balance, June 30, 2022	$	2,689	$	989	$	3,678


	Six Months Ended June 30, 2021
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2020	$	2,058	$	1,145	$	3,203
Net income	—		59		59
Common stock dividends	—		(28)		(28)
Contributions from parent	138		—		138
Balance, March 31, 2021	$	2,196	$	1,176	$	3,372��
Net income	—		75		75



Common stock dividends	—		(95)		(95)

Balance, June 30, 2021	$	2,196	$	1,156	$	3,352

See the Combined Notes to Consolidated Financial Statements

Table of Contents

DELMARVA POWER & LIGHT COMPANY

STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2022		2021		2022		2021
Operating revenues
Electric operating revenues	$	295	$	262	$	643	$	562
Natural gas operating revenues	37		24		120		95
Revenues from alternative revenue programs	(2)		10		(3)		19
Operating revenues from affiliates	2		2		3		4
Total operating revenues	332		298		763		680
Operating expenses
Purchased power	116		82		253		185
Purchased fuel	19		9		61		41
Purchased power from affiliates	—		17		10		37
Operating and maintenance	45		41		97		85
Operating and maintenance from affiliates	43		39		84		79
Depreciation and amortization	56		51		113		104
Taxes other than income taxes	17		16		35		33
Total operating expenses	296		255		653		564



Operating income	36		43		110		116
Other income and (deductions)
Interest expense, net	(17)		(16)		(33)		(30)
Other, net	4		4		6		6
Total other income and (deductions)	(13)		(12)		(27)		(24)
Income before income taxes	23		31		83		92
Income taxes	2		1		6		6

Net income	$	21	$	30	$	77	$	86
Comprehensive income	$	21	$	30	$	77	$	86

See the Combined Notes to Consolidated Financial Statements

Table of Contents

DELMARVA POWER & LIGHT COMPANY

STATEMENTS OF CASH FLOWS

(Unaudited)


	Six Months Ended June 30,
(In millions)	2022		2021
Cash flows from operating activities
Net income	$	77	$	86
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	113		104

Deferred income taxes and amortization of investment tax credits	3		4

Other non-cash operating activities	13		(12)
Changes in assets and liabilities:
Accounts receivable	(8)		24
Receivables from and payables to affiliates, net	(3)		(12)
Inventories	1		—
Accounts payable and accrued expenses	12		7
Collateral received, net	180		—
Income taxes	6		14
Regulatory assets and liabilities, net	(11)		(13)
Pension and non-pension postretirement benefit contributions	(1)		—
Other assets and liabilities	1		(9)
Net cash flows provided by operating activities	383		193
Cash flows from investing activities
Capital expenditures	(194)		(211)


Changes in PHI intercompany money pool	(73)		(9)
Other investing activities	2		1
Net cash flows used in investing activities	(265)		(219)
Cash flows from financing activities
Changes in short-term borrowings	(149)		(146)
Issuance of long-term debt	125		125


Dividends paid on common stock	(56)		(63)
Contributions from parent	144		120
Other financing activities	(4)		(3)
Net cash flows provided by financing activities	60		33
Increase in cash, restricted cash, and cash equivalents	178		7
Cash, restricted cash, and cash equivalents at beginning of period	71		15
Cash, restricted cash, and cash equivalents at end of period	$	249	$	22

Supplemental cash flow information
Decrease in capital expenditures not paid	$	(5)	$	(14)

See the Combined Notes to Consolidated Financial Statements

Table of Contents

DELMARVA POWER & LIGHT COMPANY

BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	26	$	28
Restricted cash and cash equivalents	223		43
Accounts receivable
Customer accounts receivable	154		149
Customer allowance for credit losses	(22)		(18)
Customer accounts receivable, net	132		131
Other accounts receivable	55		58
Other allowance for credit losses	(8)		(8)
Other accounts receivable, net	47		50
Receivables from affiliates	—		1
Receivable from PHI intercompany pool	73		—
Inventories, net
Fossil fuel	10		11
Materials and supplies	54		54
Prepaid utility taxes	—		20

Regulatory assets	68		68

Other	29		16
Total current assets	662		422
Property, plant, and equipment (net of accumulated depreciation and amortization of $1,704 and $1,635 as of June 30, 2022 and December 31, 2021, respectively)	4,661		4,560
Deferred debits and other assets
Regulatory assets	204		212


Prepaid pension asset	156		157
Other	59		61
Total deferred debits and other assets	419		430
Total assets	$	5,742	$	5,412

See the Combined Notes to Consolidated Financial Statements

Table of Contents

DELMARVA POWER & LIGHT COMPANY

BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities
Short-term borrowings	$	—	$	149
Long-term debt due within one year	84		83
Accounts payable	141		131
Accrued expenses	40		40
Payables to affiliates	29		33

Customer deposits	27		28
Regulatory liabilities	31		25
Other	239		59
Total current liabilities	591		548
Long-term debt	1,854		1,727
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	830		803
Regulatory liabilities	415		441
Asset retirement obligations	16		16

Non-pension postretirement benefits obligations	10		11
Other	84		89
Total deferred credits and other liabilities	1,355		1,360
Total liabilities	3,800		3,635
Commitments and contingencies	0		0
Shareholder's equity
Common stock	1,353		1,209

Retained earnings	589		568
Total shareholder's equity	1,942		1,777
Total liabilities and shareholder's equity	$	5,742	$	5,412

See the Combined Notes to Consolidated Financial Statements

Table of Contents

DELMARVA POWER & LIGHT COMPANY

STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY

(Unaudited)


	Six Months Ended June 30, 2022
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2021	$	1,209	$	568	$	1,777
Net income	—		56		56
Common stock dividends	—		(41)		(41)
Contributions from parent	144		—		144
Balance, March 31, 2022	$	1,353	$	583	$	1,936
Net income	—		21		21
Common stock dividends	—		(15)		(15)

Balance, June 30, 2022	$	1,353	$	589	$	1,942


	Six Months Ended June 30, 2021
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2020	$	1,089	$	587	$	1,676
Net income	—		56		56
Common stock dividends	—		(40)		(40)
Contributions from parent	120		—		120
Balance, March 31, 2021	$	1,209	$	603	$	1,812
Net income	—		30		30
Common stock dividends	—		(23)		(23)

Balance, June 30, 2021	$	1,209	$	610	$	1,819

See the Combined Notes to Consolidated Financial Statements

Table of Contents

ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(In millions)	2022		2021		2022		2021
Operating revenues
Electric operating revenues	$	323	$	306	$	668	$	605
Revenues from alternative revenue programs	(15)		12		(12)		23
Operating revenues from affiliates	1		1		2		1
Total operating revenues	309		319		658		629
Operating expenses
Purchased power	123		149		299		302
Purchased power from affiliate	—		5		2		9
Operating and maintenance	50		39		97		82
Operating and maintenance from affiliates	36		34		73		68
Depreciation and amortization	72		40		118		87
Taxes other than income taxes	2		2		4		4
Total operating expenses	283		269		593		552



Operating income	26		50		65		77
Other income and (deductions)
Interest expense, net	(17)		(14)		(32)		(29)

Other, net	2		—		5		2
Total other income and (deductions)	(15)		(14)		(27)		(27)
Income before income taxes	11		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

Table of Contents

ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)


	Six Months Ended June 30,
(In millions)	2022		2021
Cash flows from operating activities
Net income	$	37	$	51
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	118		87
Deferred income taxes and amortization of investment tax credits	—		(2)
Other non-cash operating activities	25		(14)
Changes in assets and liabilities:
Accounts receivable	(20)		(30)
Receivables from and payables to affiliates, net	(10)		4
Inventories	(2)		2
Accounts payable and accrued expenses	9		(2)
Collateral received, net	137		—
Income taxes	8		2
Regulatory assets and liabilities, net	(11)		18
Pension and non-pension postretirement benefit contributions	(7)		(3)
Other assets and liabilities	(63)		(43)
Net cash flows provided by operating activities	221		70
Cash flows from investing activities
Capital expenditures	(179)		(239)



Net cash flows used in investing activities	(179)		(239)
Cash flows from financing activities
Changes in short-term borrowings	(144)		(9)


Issuance of long-term debt	175		350
Retirement of long-term debt	—		(249)

Dividends paid on common stock	(38)		(229)
Contributions from parent	173		303
Other financing activities	(4)		(4)
Net cash flows provided by financing activities	162		162
Increase (decrease) in cash, restricted cash, and cash equivalents	204		(7)
Cash, restricted cash, and cash equivalents at beginning of period	29		30
Cash, restricted cash, and cash equivalents at end of period	$	233	$	23

Supplemental cash flow information
Decrease in capital expenditures not paid	$	(19)	$	(13)

See the Combined Notes to Consolidated Financial Statements

Table of Contents

ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	233	$	29

Accounts receivable
Customer accounts receivable	194		190
Customer allowance for credit losses	(45)		(49)
Customer accounts receivable, net	149		141
Other accounts receivable	70		76
Other allowance for credit losses	(14)		(15)
Other accounts receivable, net	56		61

Receivables from affiliates	1		2

Inventories, net	38		36


Prepaid utility taxes	40		—
Regulatory assets	135		61
Other	7		3
Total current assets	659		333
Property, plant, and equipment (net of accumulated depreciation and amortization of $1,491 and $1,420 as of June 30, 2022 and December 31, 2021, respectively)	3,798		3,729
Deferred debits and other assets
Regulatory assets	535		430



Prepaid pension asset	26		27

Other	34		37
Total deferred debits and other assets	595		494
Total assets	$	5,052	$	4,556

See the Combined Notes to Consolidated Financial Statements

Table of Contents

ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY

CONSOLIDATED BALANCE SHEETS

(Unaudited)


(In millions)	June 30, 2022		December 31, 2021
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities
Short-term borrowings	$	—	$	144
Long-term debt due within one year	3		3
Accounts payable	157		165
Accrued expenses	43		44
Payables to affiliates	20		31



Customer deposits	18		18
Regulatory liabilities	29		28
PPA termination obligation	87		—
Other	149		12
Total current liabilities	506		445
Long-term debt	1,754		1,579
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	695		682
Regulatory liabilities	197		214


Non-pension postretirement benefit obligations	10		12



Other	143		49
Total deferred credits and other liabilities	1,045		957
Total liabilities	3,305		2,981
Commitments and contingencies	0		0
Shareholder's equity
Common stock	1,763		1,590
Retained deficit	(16)		(15)

Total shareholder's equity	1,747		1,575
Total liabilities and shareholder's equity	$	5,052	$	4,556

See the Combined Notes to Consolidated Financial Statements

Table of Contents

ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY

(Unaudited)


	Six Months Ended June 30, 2022
(In millions)	Common Stock		Retained Deficit		Total Shareholder's Equity
Balance, December 31, 2021	$	1,590	$	(15)	$	1,575
Net income	—		26		26
Common stock dividends	—		(19)		(19)
Contributions from parent	173		—		173
Balance, March 31, 2022	$	1,763	$	(8)	$	1,755
Net income	—		11		11
Common stock dividends	—		(19)		(19)

Balance, June 30, 2022	$	1,763	$	(16)	$	1,747


	Six Months Ended June 30, 2021
(In millions)	Common Stock		Retained Earnings (Deficit)		Total Shareholder's Equity
Balance, December 31, 2020	$	1,271	$	127	$	1,398
Net income	—		14		14
Common stock dividends	—		(14)		(14)
Contributions from parent	303		—		303
Balance, March 31, 2021	$	1,574	$	127	$	1,701
Net income	—		37		37
Common stock dividends	—		(215)		(215)

Balance, June 30, 2021	$	1,574	$	(51)	$	1,523

See the Combined Notes to Consolidated Financial Statements

Table of Contents

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 Company

Purchase and regulated retail sale of electricity

Northern Illinois, including the City of Chicago

Transmission and distribution of electricity to retail customers

PECO Energy Company

Purchase and regulated retail sale of electricity and natural gas

Southeastern Pennsylvania, including the City of Philadelphia (electricity)

Transmission and distribution of electricity and distribution of natural gas to retail customers

Pennsylvania counties surrounding the City of Philadelphia (natural gas)

Baltimore Gas and Electric Company

Purchase and regulated retail sale of electricity and natural gas

Central Maryland, including the City of Baltimore (electricity and natural gas)

Transmission and distribution of electricity and distribution of natural gas to retail customers

Pepco Holdings LLC

Utility services holding company engaged, through its reportable segments Pepco, DPL, and ACE

Service Territories of Pepco, DPL, and ACE

Potomac Electric
Power Company

Purchase and regulated retail sale of electricity

District of Columbia, and major portions of Montgomery and Prince George’s Counties, Maryland

Transmission and distribution of electricity to retail customers

Delmarva Power &
Light Company

Purchase and regulated retail sale of electricity and natural gas

Portions of Delaware and Maryland (electricity)

Transmission and distribution of electricity and distribution of natural gas to retail customers

Portions of New Castle County, Delaware (natural gas)

Atlantic City Electric Company

Purchase and regulated retail sale of electricity

Portions of Southern New Jersey

Transmission and distribution of electricity to retail customers

Basis of Presentation

This is a combined quarterly report of all Registrants. The Notes to the Consolidated Financial Statements apply to the Registrants as indicated parenthetically next to each corresponding disclosure. When appropriate, the Registrants are named specifically for their related activities and disclosures. Each of the Registrant’s Consolidated Financial Statements includes the accounts of its subsidiaries. All intercompany transactions have been eliminated, except for the historical transactions between the Utility Registrants and Generation for the purposes of presenting discontinued operations in all periods presented in the Consolidated Statements of Operations and Comprehensive Income.

Through its business services subsidiary, BSC, Exelon provides its subsidiaries with a variety of support services at cost, including legal, human resources, financial, information technology, and supply management services. PHI also has a business services subsidiary, PHISCO, which provides a variety of support services at cost, including legal, accounting, 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 June 30, 2022 and for the three and six months ended 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

Table of Contents

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.

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.

•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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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 2 — Discontinued Operations

•Transition Services Agreement (TSA) – governs the terms and conditions of the services that Exelon will provide to Constellation and Constellation will provide to Exelon for an expected period of two years, provided that certain services may be longer than the term and services may be extended with approval from both parties. The services include specified accounting, finance, information technology, human resources, employee benefits and other services that have historically been provided on a centralized basis by BSC. For the three months ended June 30, 2022, the amounts Exelon billed Constellation and Constellation billed Exelon for these services were $69 million recorded in Other income, net and $11 million recorded in Operating and maintenance expense, respectively. Additionally, for the period from February 1, 2022 to June 30, 2022, the amounts Exelon billed Constellation and Constellation billed Exelon for these services were $125 million recorded in Other income, net and $20 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 9 — Asset Retirement Obligations of the Combined Notes to Consolidated Financial Statements of the 2021 Recast Form 10-K and Note 15 — Related Party Transactions for additional information.

Discontinued Operations

The separation represented a strategic shift that would have a major effect on Exelon’s operations and financial results. Accordingly, the separation meets the criteria for discontinued operations.

The following table presents the results of Constellation that have been reclassified from continuing operations and included in discontinued operations within Exelon’s Consolidated Statements of Operations and Comprehensive Income for the three and six months ended June 30, 2022 and June 30, 2021.

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

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 2 — Discontinued Operations

external bankers, accountants, appraisers, lawyers, external counsels and other advisors, among others, who are involved in the negotiation, appraisal, due diligence and regulatory approval of the separation. Transition costs are primarily employee-related costs such as recruitment expenses, costs to establish certain stand-alone functions and information technology systems, professional services fees and other separation-related costs during the transition to separate Generation. For the purposes of reporting discontinued operations, these results also include transactions between Generation and the Utility Registrants that were historically eliminated within Exelon’s Consolidated Statements of Operations as these transactions will be ongoing after the separation. Certain BSC costs that were historically allocated to Generation are presented as part of continuing operations in Exelon’s Consolidated Statements of Operations as these costs do not qualify as expenses of the discontinued operations per the accounting rules.


	Three Months Ended June 30,		Six Months Ended June 30,
	2021		2022		2021
Operating revenues
Competitive business revenues	$	3,900	$	1,855	$	9,165
Competitive business revenues from affiliates	255		161		549
Total operating revenues	4,155		2,016		9,714
Operating expenses
Competitive businesses purchased power and fuel	1,947		1,138		6,557

Operating and maintenance(a)	1,382		371		2,287

Depreciation and amortization	930		94		1,869
Taxes other than income taxes	118		44		239
Total operating expenses	4,377		1,647		10,952
Gain on sales of assets and businesses	8		10		79
Operating income (loss)	(214)		379		(1,159)
Other income and (deductions)
Interest expense, net	(72)		(20)		(140)

Other, net	508		(281)		675
Total other income and (deductions)	436		(301)		535
Income (loss) before income taxes	222		78		(624)
Income taxes	71		(40)		13
Equity in losses of unconsolidated affiliates	(1)		(1)		(3)
Net income (loss)	150		117		(640)
Net income attributable to noncontrolling interests	75		1		99
Net income (loss) from discontinued operations	$	75	$	116	$	(739)

__________

(a)Includes transaction and transition costs related to the separation of $52 million for the six months ended June 30, 2022 and $4 million and $7 million for the three and six months ended June 30, 2021, respectively. See discussion above for additional information.

There were no assets and liabilities of discontinued operations included in Exelon’s Consolidated Balance Sheet as of June 30, 2022. Constellation had net assets of $11,573 million that separated on February 1, 2022 that resulted in a reduction to Exelon’s equity during the six months ended June 30, 2022. Refer to the Distribution of Constellation line in Exelon’s Consolidated Statement of Changes in Shareholders’ Equity for further information.

The following table presents the assets and liabilities of discontinued operations in Exelon’s Consolidated Balance Sheet as of December 31, 2021:

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 2 — Discontinued Operations


	December 31, 2021
ASSETS
Current assets
Cash and cash equivalents	$	510
Restricted cash and cash equivalents	72
Accounts receivable
Customer accounts receivable	1,724
Customer allowance for credit losses	(55)
Customer accounts receivable, net	1,669
Other accounts receivable	596
Other allowance for credit losses	(4)
Other accounts receivable, net	592
Mark-to-market derivative assets	2,169
Inventories, net
Fossil fuel and emission allowances	284
Materials and supplies	1,004
Renewable energy credits	529
Assets held for sale	13
Other	993
Total current assets of discontinued operations	7,835
Property, plant, and equipment (net of accumulated depreciation and amortization of $15,888)	19,661
Deferred debits and other assets
Nuclear decommissioning trust funds	15,938
Investments	193

Mark-to-market derivative assets	949
Other	1,768
Total property, plant, and equipment, deferred debits, and other assets of discontinued operations	38,509
Total assets of discontinued operations	$	46,344

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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 2 — Discontinued Operations


	December 31, 2021
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities
Short-term borrowings	$	2,082
Long-term debt due within one year	1,220
Accounts payable	1,757
Accrued expenses	818
Mark-to-market derivative liabilities	981

Renewable energy credit obligation	779
Liabilities held for sale	3
Other	300
Total current liabilities of discontinued operations	7,940
Long-term debt	4,575
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	3,583
Asset retirement obligations	12,819
Pension obligations	939
Non-pension postretirement benefit obligations	876
Spent nuclear fuel obligation	1,210
Mark-to-market derivative liabilities	513

Other	1,161
Total long-term debt, deferred credits, and other liabilities of discontinued operations	25,676
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 six months ended June 30, 2022 and June 30, 2021.


	Six Months Ended June 30,
	2022		2021
Non-cash items included in net income (loss) from discontinued operations:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	$	207	$	2,686
Asset impairments	—		493
Gain on sales of assets and businesses	9		(79)
Deferred income taxes and amortization of investment tax credits	(143)		(268)
Net fair value changes related to derivatives	(59)		(490)
Net realized and unrealized losses (gains) on NDT fund investments	205		(376)
Net unrealized losses (gains) on equity investments	16		(96)
Other decommissioning-related activity	36		(636)
Cash flows from investing activities:
Capital expenditures	(227)		(731)
Collection of DPP	169		2,209
Supplemental cash flow information:
Decrease in capital expenditures not paid	(128)		(66)
Increase in DPP	348		1,958
Increase in PP&E related to ARO update	335		—

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 3 — Regulatory Matters

3. Regulatory Matters (All Registrants)

As discussed in Note 3 — Regulatory Matters of the 2021 Recast Form 10-K, the Registrants are involved in rate and regulatory proceedings at FERC and their state commissions. The following discusses developments in 2022 and updates to the 2021 Recast Form 10-K.

Distribution Base Rate Case Proceedings

The following tables show the completed and pending distribution base rate case proceedings in 2022.

Completed Distribution Base Rate Case Proceedings


Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement Increase		Approved Revenue Requirement Increase		Approved ROE		Approval Date	Rate Effective Date
ComEd - Illinois(a)	April 16, 2021	Electric	$	51	$	46	7.36	%	December 1, 2021	January 1, 2022
PECO - Pennsylvania	March 30, 2021	Electric	246		132		N/A(b)		November 18, 2021	January 1, 2022
BGE - Maryland(c)	May 15, 2020 (amended September 11, 2020)	Electric	203		140		9.50	%	December 16, 2020	January 1, 2021
		Natural Gas	108		74		9.65	%
Pepco - District of Columbia(d)	May 30, 2019 (amended June 1, 2020)	Electric	136		109		9.275	%	June 8, 2021	July 1, 2021
Pepco - Maryland(e)	October 26, 2020 (amended March 31, 2021)	Electric	104		52		9.55	%	June 28, 2021	June 28, 2021
DPL - Maryland(f)	September 1, 2021 (amended December 23, 2021)	Electric	27		13		9.60	%	March 2, 2022	March 2, 2022
ACE - New Jersey(g)	December 9, 2020 (amended February 26, 2021)	Electric	67		41		9.60	%	July 14, 2021	January 1, 2022

__________

(a)ComEd's 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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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 3 — Regulatory Matters

(e)Reflects a three-year cumulative multi-year plan for April 1, 2021 through March 31, 2024. The MDPSC awarded Pepco electric incremental revenue requirement increases of $21 million, $16 million, and $15 million, before offsets, for the 12-month periods ending March 31, 2022, 2023, and 2024, respectively. Pepco proposed to utilize certain tax benefits to fully offset the increase through 2023 and partially offset customer rate increases in 2024. However, the MDPSC only utilized the acceleration of refunds for certain tax benefits to fully offset the increases such that customer rates remain unchanged through March 31, 2022. On February 23, 2022, the MDPSC chose to offset 25% of the cumulative revenue requirement increase for the 12-month period ending March 31, 2023. Whether certain tax benefits will be used to offset the customer rate increases for the 12-month period ending March 31, 2024 has not been decided, and Pepco cannot predict the outcome.

(f)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/Jurisdiction

Filing Date

Service

Requested Revenue Requirement Increase

Requested ROE

Expected Approval Timing

ComEd - Illinois(a)

April 15, 2022

Electric

199

7.85

Fourth quarter of 2022

PECO - Pennsylvania

March 31, 2022

Natural Gas

10.95

Fourth quarter of 2022

DPL - Delaware(b)

January 14, 2022 (amended February 28, 2022)

Natural Gas

10.30

First quarter of 2023

DPL - Maryland(c)

May 19, 2022

Electric

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 - Regulatory Matters of the 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).

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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

For 2022, the following total increases/(decreases) were included in the Utility Registrants' electric transmission formula rate update:


Registrant(a)	Initial Revenue Requirement Increase		Annual Reconciliation (Decrease) Increase		Total Revenue Requirement Increase			Allowed Return on Rate Base(b)		Allowed ROE(c)
ComEd	$	24	$	(24)	$	—		8.11	%	11.50	%
PECO	23		16		39			7.30	%	10.35	%
BGE	25		(4)		16		(d)	7.30	%	10.50	%
Pepco	16		15		31			7.60	%	10.50	%
DPL	9		2		11			7.09	%	10.50	%
ACE	21		13		34			7.18	%	10.50	%

__________

(a)All rates are effective June 1, 2022 - May 31, 2023, subject to review by interested parties pursuant to review protocols of each 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.

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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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 3 — Regulatory Matters

Excess Deferred Income Taxes

The ICC initiated a docket to accelerate and fully credit to customers TCJA unprotected property-related EDIT no later than December 31, 2025. On July 7, 2022, the ICC issued a final order on the schedule for the acceleration of EDIT amortization, adopting the proposal as submitted by several parties, including ComEd, ICC Staff, the Illinois Attorney General's Office, and the Citizens Utility Board. EDIT amortization 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 the outcome of these proceedings.

See Note 3 — Regulatory Matters of the 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 Increase		Annual Reconciliation Decrease		Total Revenue Requirement Increase		Requested Return on Rate Base(a)		Requested ROE
$	66	$	(16)	$	50	5.94	%	7.85	%

__________

(a)The requested revenue requirement increase provides for a weighted average debt and equity return 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 June 30, 2022, the $180 million liability for the contract termination fee consists of $87 million and $93 million included in Other current liabilities and Other deferred credits and other liabilities, respectively, in Exelon's Consolidated Balance Sheet. The current and noncurrent liability is included in PPA termination obligation and Other deferred credits and other liabilities, respectively, in PHI's and ACE's Consolidated Balance Sheets. 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 in Exelon's, PHI's, and ACE's Consolidated Statements of 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

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 $254 million primarily due to an increase of $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 $325 million primarily due to a decrease of $305 million in the Decommissioning the Regulatory Agreement Units regulatory liability and $12 million in the Electric Energy and Natural Gas Costs regulatory liability.

BGE. Regulatory assets decreased $49 million primarily due to a decrease of $20 million in the Under-recovered revenue decoupling regulatory asset, $14 million in the Electric Energy and Natural Gas Costs regulatory asset, and $13 million in the Energy Efficiency and Demand Response Programs regulatory asset.

Pepco. 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 $44 million primarily due to a decrease of $46 million in the Deferred Income Taxes regulatory liability.

ACE. Regulatory assets increased $179 million primarily due to an increase in the Electric Energy Costs regulatory asset as a result of the PPA termination. Regulatory liabilities decreased $16 million primarily due to a decrease of $13 million in the Deferred Income Taxes 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)		ACE
June 30, 2022	$	49	$	4	$	—	$	32	$	13	$	11	$	2	$	—

December 31, 2021	43		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 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.

The following table provides a rollforward of the contract liabilities reflected in Exelon's, PHI's, Pepco's, DPL's, and ACE's Consolidated Balance Sheets for the three and six months ended June 30, 2022 and 2021. As of June 30, 2022 and December 31, 2021, ComEd's, PECO's, and BGE's contract liabilities were immaterial.



	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, 2022	107		107		85		11		11
Revenues recognized	(2)		(2)		(1)		—		(1)
Balance as of June 30, 2022	$	105	$	105	$	84	$	11	$	10



	Exelon(a)		PHI(a)		Pepco(a)		DPL(a)		ACE(a)
Balance as of December 31, 2020	$	118	$	118	$	94	$	12	$	12
Revenues recognized	(2)		(2)		(2)		—		—
Balance as of March 31, 2021	116		116		92		12		12
Revenues recognized	(3)		(3)		(1)		(1)		(1)
Balance as of June 30, 2021	$	113	$	113	$	91	$	11	$	11

__________

(a)Revenues recognized in the three and six months ended June 30, 2022 and 2021, were included in the contract liabilities at December 31, 2021 and 2020, respectively.

Transaction Price Allocated to Remaining Performance Obligations

The following table shows the amounts of future revenues expected to be recorded in each year for performance obligations that are unsatisfied or partially unsatisfied as of June 30, 2022. 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.

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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


	2022		2023		2024		2025		2026 and thereafter		Total
Exelon	$	4	$	8	$	6	$	5	$	82	$	105
PHI	4		8		6		5		82		105
Pepco	3		6		5		5		65		84
DPL	1		1		—		—		9		11
ACE	—		1		1		—		8		10

Revenue Disaggregation

The Registrants disaggregate revenue recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. See Note 5 — Segment Information for the presentation of the Registrant'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 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 June 30, 2022 and 2021



	ComEd		PECO		BGE		PHI		Other(a)		Intersegment Eliminations		Exelon
Operating revenues(b):
2022
Electric revenues	$	1,425	$	708	$	629	$	1,182	$	—	$	(6)	$	3,938
Natural gas revenues	—		108		157		37		—		(1)		301
Shared service and other revenues	—		—		—		2		384		(386)		—
Total operating revenues	$	1,425	$	816	$	786	$	1,221	$	384	$	(393)	$	4,239
2021
Electric revenues	$	1,517	$	610	$	558	$	1,113	$	—	$	(9)	$	3,789
Natural gas revenues	—		83		124		24		—		—		231
Shared service and other revenues	—		—		—		3		524		(527)		—
Total operating revenues	$	1,517	$	693	$	682	$	1,140	$	524	$	(536)	$	4,020

Intersegment revenues(c):
2022	$	3	$	1	$	3	$	2	$	384	$	(393)	$	—
2021	5		2		7		4		522		(535)		5
Depreciation and amortization:
2022	$	328	$	93	$	152	$	240	$	16	$	1	$	830
2021	296		87		141		194		18		—		736
Operating expenses:
2022	$	1,039	$	639	$	717	$	1,066	$	460	$	(378)	$	3,543
2021	1,196		552		620		955		495		(374)		3,444
Interest expense, net:
2022	$	104	$	43	$	36	$	73	$	101	$	1	$	358
2021	98		42		34		67		83		—		324
Income (loss) from continuing operations before income taxes:
2022	$	293	$	142	$	38	$	101	$	(62)	$	(1)	$	511
2021	238		106		37		138		(46)		(144)		329
Income Taxes:
2022	$	66	$	9	$	1	$	1	$	(31)	$	—	$	46
2021	46		2		(8)		(3)		(27)		(7)		3
Net income (loss) from continuing operations:
2022	$	227	$	133	$	37	$	100	$	(31)	$	(1)	$	465
2021	192		104		45		141		(19)		(137)		326
Capital Expenditures:
2022	$	591	$	314	$	275	$	367	$	38	$	—	$	1,585
2021	549		282		284		433		15		—		1,563

__________

(a)Other primarily includes Exelon’s corporate operations, shared service entities, and other financing and investment activities.

(b)Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 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:



	Pepco		DPL		ACE		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
2021	1		2		1		95		(95)		4
Depreciation and amortization:
2022	$	105	$	56	$	72	$	7	$	—	$	240
2021	96		51		40		7		—		194
Operating expenses:
2022	$	487	$	296	$	283	$	99	$	(99)	$	1,066
2021	429		255		269		97		(95)		955
Interest expense, net:
2022	$	38	$	17	$	17	$	1	$	—	$	73
2021	35		16		14		2		—		67
Income (loss) before income taxes:
2022	$	69	$	23	$	11	$	(2)	$	—	$	101
2021	72		31		36		(1)		—		138
Income Taxes:
2022	$	(1)	$	2	$	—	$	—	$	—	$	1
2021	(3)		1		(1)		—		—		(3)
Net income (loss):
2022	$	70	$	21	$	11	$	(2)	$	—	$	100
2021	75		30		37		(1)		—		141
Capital Expenditures:
2022	$	184	$	91	$	92	$	—	$	—	$	367
2021	219		99		116		(1)		—		433

__________

(a)Other primarily includes PHI’s corporate operations, shared service entities, and other financing and investment activities.

(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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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 5 — Segment Information



	Three Months Ended June 30, 2022
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Electric revenues
Residential	$	819	$	431	$	334	$	548	$	234	$	155	$	159
Small commercial & industrial	312		126		70		140		35		51		54
Large commercial & industrial	11		72		129		332		250		30		52
Public authorities & electric railroads	5		7		7		15		8		3		4
Other(a)	234		68		99		164		54		57		55
Total electric revenues(b)	$	1,381	$	704	$	639	$	1,199	$	581	$	296	$	324
Natural gas revenues
Residential	$	—	$	71	$	96	$	17	$	—	$	17	$	—
Small commercial & industrial	—		29		18		8		—		8		—
Large commercial & industrial	—		—		35		3		—		3		—
Transportation	—		6		—		3		—		3		—
Other(c)	—		2		12		6		—		6		—
Total Natural gas revenues(d)	$	—	$	108	$	161	$	37	$	—	$	37	$	—
Total revenues from contracts with customers	$	1,381	$	812	$	800	$	1,236	$	581	$	333	$	324

Other revenues
Revenues from alternative revenue programs	$	35	$	—	$	(20)	$	(17)	$	(1)	$	(2)	$	(15)
Other electric revenues(e)	9		4		4		2		1		1		—
Other natural gas revenues(e)	—		—		2		—		—		—		—

Total other revenues	$	44	$	4	$	(14)	$	(15)	$	—	$	(1)	$	(15)
Total revenues for reportable segments	$	1,425	$	816	$	786	$	1,221	$	581	$	332	$	309

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 customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Electric revenues
Residential	$	759	$	383	$	299	$	537	$	223	$	147	$	167
Small commercial & industrial	377		99		60		124		32		46		46
Large commercial & industrial	138		59		108		257		188		22		47
Public authorities & electric railroads	11		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.

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


	ComEd		PECO		BGE		PHI		Other(a)		Intersegment Eliminations		Exelon
Operating revenues(b):
2022
Electric revenues	$	3,158	$	1,449	$	1,366	$	2,501	$	—	$	(14)	$	8,460
Natural gas revenues	—		414		574		120		—		(2)		1,106
Shared service and other revenues	—		—		—		5		961		(966)		—
Total operating revenues	$	3,158	$	1,863	$	1,940	$	2,626	$	961	$	(982)	$	9,566
2021
Electric revenues	$	3,052	$	1,271	$	1,190	$	2,283	$	—	$	(16)	$	7,780
Natural gas revenues	—		311		466		95		—		—		872
Shared service and other revenues	—		—		—		6		1,013		(1,019)		—
Total operating revenues	$	3,052	$	1,582	$	1,656	$	2,384	$	1,013	$	(1,035)	$	8,652

Intersegment revenues(c):
2022	$	8	$	2	$	10	$	6	$	961	$	(981)	$	6
2021	11		4		13		7		1,010		(1,033)		12
Depreciation and amortization:
2022	$	649	$	185	$	322	$	459	$	32	$	—	$	1,647
2021	589		173		293		404		35		—		1,494
Operating expenses:
2022	$	2,444	$	1,432	$	1,636	$	2,282	$	1,086	$	(909)	$	7,971
2021	2,406		1,231		1,372		2,013		943		(713)		7,252
Interest expense, net:
2022	$	204	$	84	$	71	$	143	$	195	$	—	$	697
2021	193		80		67		134		169		—		643
Income (loss) from continuing operations before income taxes:
2022	$	534	$	363	$	244	$	238	$	(125)	$	(45)	$	1,209
2021	475		283		233		273		(80)		(292)		892
Income Taxes:
2022	$	119	$	24	$	10	$	8	$	114	$	(12)	$	263
2021	85		12		(21)		5		(19)		(20)		42
Net income (loss) from continuing operations:
2022	$	415	$	339	$	234	$	230	$	(239)	$	(33)	$	946
2021	390		271		254		269		(61)		(272)		851
Capital Expenditures:
2022	$	1,208	$	658	$	578	$	776	$	60	$	—	$	3,280
2021	1,162		577		620		889		61		—		3,309
Total assets:
June 30, 2022	$	37,194	$	14,216	$	13,093	$	25,592	$	6,345	$	(4,145)	$	92,295
December 31, 2021	36,470		13,824		12,324		24,744		7,626		(8,319)		86,669

__________

(a)Other primarily includes Exelon’s corporate operations, shared service entities, and other financing and investment activities.

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 5 — Segment Information

(c)See Note 15 — Related Party Transactions for additional information on intersegment revenues.

PHI:


	Pepco		DPL		ACE		Other(a)		Intersegment Eliminations		PHI
Operating revenues(b):
2022
Electric revenues	$	1,195	$	643	$	658	$	—	$	5	$	2,501
Natural gas revenues	—		120		—		—		—		120
Shared service and other revenues	—		—		—		205		(200)		5
Total operating revenues	$	1,195	$	763	$	658	$	205	$	(195)	$	2,626
2021
Electric revenues	$	1,076	$	585	$	629	$	—	$	(7)	$	2,283
Natural gas revenues	—		95		—		—		—		95
Shared service and other revenues	—		—		—		189		(183)		6
Total operating revenues	$	1,076	$	680	$	629	$	189	$	(190)	$	2,384
Intersegment revenues(c):
2022	$	2	$	3	$	2	$	195	$	(196)	$	6
2021	3		4		1		189		(190)		7
Depreciation and amortization:
2022	$	213	$	113	$	118	$	15	$	—	$	459
2021	199		104		87		14		—		404
Operating expenses:
2022	$	1,034	$	653	$	593	$	197	$	(195)	$	2,282
2021	895		564		552		192		(190)		2,013
Interest expense, net:
2022	$	74	$	33	$	32	$	5	$	(1)	$	143
2021	69		30		29		6		—		134
Income (loss) before income taxes:
2022	$	113	$	83	$	38	$	4	$	—	$	238
2021	137		92		50		(6)		—		273
Income Taxes:
2022	$	(3)	$	6	$	1	$	4	$	—	$	8
2021	3		6		(1)		(3)		—		5
Net income (loss):
2022	$	116	$	77	$	37	$	—	$	—	$	230
2021	134		86		51		(2)		—		269
Capital Expenditures:
2022	$	402	$	194	$	179	$	1	$	—	$	776
2021	439		211		239		—		—		889
Total assets:
June 30, 2022	$	10,226	$	5,742	$	5,052	$	4,775	$	(203)	$	25,592
December 31, 2021	9,903		5,412		4,556		4,933		(60)		24,744

__________

(a)Other primarily includes PHI’s corporate operations, shared service entities, and other financing and investment activities.

(c)Includes intersegment revenues with ComEd, BGE, and PECO, which are eliminated at Exelon.

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
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Electric revenues
Residential	$	1,675	$	918	$	752	$	1,200	$	509	$	362	$	329
Small commercial & industrial	736		237		151		281		73		107		101
Large commercial & industrial	165		136		260		655		503		56		96
Public authorities & electric railroads	20		15		14		31		16		7		8
Other(a)	472		130		196		359		100		113		136
Total electric revenues(b)	$	3,068	$	1,436	$	1,373	$	2,526	$	1,201	$	645	$	670
Natural gas revenues
Residential	$	—	$	289	$	378	$	68	$	—	$	68	$	—
Small commercial & industrial	—		105		63		29		—		29		—
Large commercial & industrial	—		—		100		6		—		6		—
Transportation	—		14		—		7		—		7		—
Other(c)	—		5		47		10		—		10		—
Total natural gas revenues(d)	$	—	$	413	$	588	$	120	$	—	$	120	$	—
Total revenues from contracts with customers	$	3,068	$	1,849	$	1,961	$	2,646	$	1,201	$	765	$	670

Other revenues
Revenues from alternative revenue programs	$	75	$	6	$	(32)	$	(22)	$	(7)	$	(3)	$	(12)
Other electric revenues(e)	15		7		8		2		1		1		—
Other natural gas revenues(e)	—		1		3		—		—		—		—

Total other revenues	$	90	$	14	$	(21)	$	(20)	$	(6)	$	(2)	$	(12)
Total revenues for reportable segments	$	3,158	$	1,863	$	1,940	$	2,626	$	1,195	$	763	$	658

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, 2021
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Electric revenues
Residential	$	1,502	$	816	$	662	$	1,142	$	476	$	337	$	329
Small commercial & industrial	744		199		129		242		65		92		85
Large commercial & industrial	271		116		213		505		372		43		90
Public authorities & electric railroads	22		17		13		30		16		7		7
Other(a)	433		106		165		283		101		87		95
Total electric revenues(b)	$	2,972	$	1,254	$	1,182	$	2,202	$	1,030	$	566	$	606
Natural gas revenues
Residential	$	—	$	215	$	297	$	57	$	—	$	57	$	—
Small commercial & industrial	—		81		48		24		—		24		—
Large commercial & industrial	—		—		81		3		—		3		—
Transportation	—		12		—		8		—		8		—
Other(c)	—		3		36		2		—		3		—
Total natural gas revenues(d)	$	—	$	311	$	462	$	94	$	—	$	95	$	—
Total revenues from contracts with customers	$	2,972	$	1,565	$	1,644	$	2,296	$	1,030	$	661	$	606

Other revenues
Revenues from alternative revenue programs	$	64	$	17	$	8	$	88	$	46	$	19	$	23
Other electric revenues(e)	16		—		3		—		—		—		—
Other natural gas revenues(e)	—		—		1		—		—		—		—

Total other revenues	$	80	$	17	$	12	$	88	$	46	$	19	$	23
Total revenues for reportable segments	$	3,052	$	1,582	$	1,656	$	2,384	$	1,076	$	680	$	629

__________

(a)Includes revenues from transmission revenue from PJM, wholesale electric revenue and mutual assistance revenue.

(b)Includes operating revenues from affiliates in 2022 and 2021 respectively of:

•$8 million, $11 million at ComEd

•$2 million, $3 million at PECO

•$3 million, $5 million at BGE

•$6 million, $7 million at PHI

•$2 million, $3 million at Pepco

•$3 million, $4 million at DPL

•$2 million, $1 million at ACE

(c)Includes revenues from off-system natural gas sales.

(d)Includes operating revenues from affiliates in 2022 and 2021 respectively of:

•less than $1 million, $1 million at PECO

•$7 million, $7 million at BGE

(e)Includes late payment charge revenues.

Table of Contents

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
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of March 31, 2022	$	389	$	92	$	125	$	59	$	113	$	40	$	24	$	49
Plus: Current period (benefit) provision for expected credit losses	(9)		(5)		(10)		2		4		5		—		(1)
Less: Write-offs, net of recoveries(a)	26		6		8		4		8		3		2		3
Balance as of June 30, 2022	$	354	$	81	$	107	$	57	$	109	$	42	$	22	$	45

	Three Months Ended June 30, 2021
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of March 31, 2021	$	377	$	103	$	130	$	43	$	101	$	41	$	25	$	35
Plus: Current period (benefit) provision for expected credit losses	(42)		(9)		(14)		(14)		(5)		(1)		(5)		1
Less: Write-offs, net of recoveries(a)	15		5		5		2		3		2		1		—
Balance as of June 30, 2021	$	320	$	89	$	111	$	27	$	93	$	38	$	19	$	36

	Six Months Ended June 30, 2022
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2021	$	320	$	73	$	105	$	38	$	104	$	37	$	18	$	49
Plus: Current period provision for expected credit losses(b)	101		21		21		28		31		16		7		8
Less: Write-offs, net of recoveries(a)(c)	67		13		19		9		26		11		3		12
Balance as of June 30, 2022	$	354	$	81	$	107	$	57	$	109	$	42	$	22	$	45

	Six Months Ended June 30, 2021
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	334	$	97	$	116	$	35	$	86	$	32	$	22	$	32
Plus: Current period provision (benefit) for expected credit losses	28		12		6		(5)		15		10		1		4
Less: Write-offs, net of recoveries(a)	42		20		11		3		8		4		4		—
Balance as of June 30, 2021	$	320	$	89	$	111	$	27	$	93	$	38	$	19	$	36

__________

(a)Recoveries were not material to the Registrants.

(b)For BGE, Pepco, and ACE, the increase is primarily as a result of increased receivable balances due to the increased aging of receivables.

(c)For ACE, the increase in 2022 is primarily related to the termination of the moratorium, which beginning in March 2020, prevented customer disconnections for non-payment. With disconnection activities restarting in January 2022, write-offs of aging accounts receivable increased throughout the year.

Table of Contents

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
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of March 31, 2022	$	81	$	20	$	9	$	11	$	41	$	18	$	9	$	14
Plus: Current period provision (benefit) for expected credit losses	2		(2)		2		1		1		2		(1)		—
Less: Write-offs, net of recoveries(a)	2		—		1		1		—		—		—		—
Balance as of June 30, 2022	$	81	$	18	$	10	$	11	$	42	$	20	$	8	$	14

	Three Months Ended June 30, 2021
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of March 31, 2021	$	79	$	22	$	11	$	9	$	37	$	15	$	10	$	12
Plus: Current period (benefit) provision for expected credit losses	(5)		(3)		(3)		—		1		1		(1)		1
Less: Write-offs, net of recoveries(a)	3		1		1		1		—		—		—		—
Balance as of June 30, 2021	$	71	$	18	$	7	$	8	$	38	$	16	$	9	$	13

	Six Months Ended June 30, 2022
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2021	$	72	$	17	$	7	$	9	$	39	$	16	$	8	$	15
Plus: Current period provision for expected credit losses	15		2		4		4		5		4		—		1
Less: Write-offs, net of recoveries(a)	6		1		1		2		2		—		—		2
Balance as of June 30, 2022	$	81	$	18	$	10	$	11	$	42	$	20	$	8	$	14

	Six Months Ended June 30, 2021
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	71	$	21	$	8	$	9	$	33	$	13	$	9	$	11
Plus: Current period provision (benefit) for expected credit losses	5		(2)		1		1		5		3		—		2
Less: Write-offs, net of recoveries(a)	5		1		2		2		—		—		—		—
Balance as of June 30, 2021	$	71	$	18	$	7	$	8	$	38	$	16	$	9	$	13

__________

(a)Recoveries were not material to the Registrants.

Unbilled Customer Revenue

The following table provides additional information about unbilled customer revenues recorded in the Registrants' Consolidated Balance Sheets as of June 30, 2022 and December 31, 2021.


	Unbilled customer revenues(a)
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
June 30, 2022	$	636	$	191	$	138	$	123	$	184	$	94	$	41	$	49
December 31, 2021	747		240		161		171		175		82		53		40

__________

(a)Unbilled customer revenues are classified in Customer accounts receivables, net in the Registrants' Consolidated Balance Sheets.

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 6 — Accounts Receivable

Other Purchases of Customer and Other Accounts Receivables

The Utility Registrants are required, under separate legislation and regulations in Illinois, Pennsylvania, Maryland, District of Columbia, Delaware, and New Jersey, to purchase certain receivables from alternative retail electric and, as applicable, natural gas suppliers that participate in the utilities' consolidated billing. The following table presents the total receivables purchased.


	Total receivables purchased
	Exelon(a)		ComEd		PECO		BGE(a)		PHI		Pepco		DPL		ACE
Six months ended June 30, 2022	$	1,911	$	456	$	518	$	391	$	546	$	342	$	104	$	100
Six months ended June 30, 2021	1,838		485		507		343		503		310		103		90

__________

(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 $15 million of receivables purchased from Generation for the six months ended June 30, 2021.

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)
	Exelon		ComEd		PECO(b)		BGE(b)		PHI		Pepco(b)		DPL		ACE(b)
U.S. Federal statutory rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit(c)	(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 rate	9.0	%	22.5	%	6.3	%	2.6	%	1.0	%	(1.4)	%	8.7	%	—	%



	Three Months Ended June 30, 2021(a)
	Exelon		ComEd		PECO(e)		BGE(e)		PHI		Pepco(e)		DPL		ACE(e)
U.S. Federal statutory rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	1.1		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 rate	0.9	%	19.3	%	1.9	%	(21.6)	%	(2.2)	%	(4.2)	%	3.2	%	(2.8)	%

__________

(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.

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)
	Exelon		ComEd		PECO(b)		BGE(b)		PHI		Pepco(b)		DPL		ACE(b)
U.S. Federal statutory rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit(c)	9.9		7.9		(0.3)		2.3		2.8		(3.8)		6.5		6.7
Plant basis differences	(3.5)		(0.5)		(11.2)		(1.0)		(1.7)		(2.5)		(0.7)		(1.2)
Excess deferred tax amortization	(11.0)		(5.8)		(3.2)		(17.8)		(18.3)		(16.3)		(19.5)		(22.9)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.1)		(0.1)		—		(0.1)		(0.1)		—		(0.2)		(0.2)
Tax credits(d)	0.8		(0.3)		—		(0.6)		(0.4)		(0.4)		(0.3)		(0.3)
Other(e)	4.7		0.1		0.3		0.3		0.1		(0.7)		0.4		(0.5)
Effective income tax rate	21.8	%	22.3	%	6.6	%	4.1	%	3.4	%	(2.7)	%	7.2	%	2.6	%


	Six Months Ended June 30, 2021(a)
	Exelon		ComEd		PECO(f)		BGE(f)		PHI		Pepco(f)		DPL		ACE(f)
U.S. Federal statutory rate	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%	21.0	%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	2.0		7.4		(2.1)		(10.5)		4.2		1.5		6.6		7.8
Plant basis differences	(3.6)		(0.6)		(11.3)		(1.6)		(1.3)		(1.8)		(0.7)		(0.7)
Excess deferred tax amortization	(12.5)		(7.0)		(3.3)		(15.9)		(20.8)		(17.2)		(19.7)		(28.3)
Amortization of investment tax credit, including deferred taxes on basis difference	(0.1)		(0.1)		—		(0.1)		(0.1)		—		(0.2)		(0.2)
Tax credits	(0.5)		(0.5)		—		(0.9)		(0.5)		(0.5)		(0.4)		(0.5)
Other	(1.6)		(2.3)		(0.1)		(1.0)		(0.7)		(0.8)		(0.1)		(1.1)
Effective income tax rate	4.7	%	17.9	%	4.2	%	(9.0)	%	1.8	%	2.2	%	6.5	%	(2.0)	%

__________

(a)Positive percentages represent income tax expense. Negative percentages represent income tax benefit.

(c)For Exelon, the higher state income taxes, net of federal income tax benefit, is primarily due to the long-term marginal state income tax rate change of $67 million and the recognition of a valuation allowance of $40 million against the net deferred tax asset position for certain standalone state filing jurisdictions, partially offset by a one-time impact associated with a state tax benefit of $43 million and indemnification adjustments pursuant to the Tax Matters Agreement of $4 million as a result of the separation.

(d)For Exelon, reflects the income tax expense related to the write-off of federal tax credits subject to recapture of $15 million as a result of the separation.

(e)For Exelon, primarily reflects the nondeductible transaction costs of approximately $19 million arising as part of the separation and indemnification adjustments pursuant to the Tax Matters Agreement of $48 million.

(f)For PECO, the lower effective tax rate is primarily related to plant basis differences attributable to tax repair deductions. For BGE, the income tax benefit is primarily due to the Maryland multi-year plan which resulted in the acceleration of certain income tax benefits. For Pepco, the income tax benefit is primarily due to the Maryland multi-year plan which resulted in the acceleration of certain income tax benefits. For ACE, the lower effective tax rate is primarily due to the acceleration of certain income tax benefits due to distribution rate case settlements.

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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

Unrecognized Tax Benefits

Exelon, PHI and ACE have the following unrecognized tax benefits as of June 30, 2022 and December 31, 2021. ComEd's, PECO's, BGE's, Pepco's, and DPL's amounts are not material.


	Exelon(a)		PHI		ACE
June 30, 2022	$	147	$	58	$	16
December 31, 2021	143		56		16

__________

(a)As of June 30, 2022, Exelon recorded a receivable of $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 June 30, 2022, ACE has $14 million of unrecognized state tax benefits that could significantly decrease within the 12 months after the reporting date based on the outcome of pending court cases involving other taxpayers. The unrecognized tax benefit, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate.

Other Tax Matters

Separation (Exelon)

In the first quarter of 2022, in connection with the separation, Exelon recorded an income tax expense related to continuing operations of $148 million primarily due to the long-term marginal state income tax rate change of $67 million discussed further below, the recognition of valuation allowances of approximately $40 million against the net deferred tax assets positions for certain standalone state filing jurisdictions, the write-off of federal and state tax credits subject to recapture of $17 million, and nondeductible transaction costs for federal and state taxes of $24 million.

Tax Matters Agreement (Exelon)

In connection with the separation, Exelon entered into a TMA with Constellation. The TMA governs the respective rights, responsibilities, and obligations between Exelon and Constellation after the separation with respect to tax liabilities, refunds and attributes for open tax years that Constellation was part of Exelon’s consolidated group for U.S. federal, state, and local tax purposes.

Indemnification for Taxes. As a former subsidiary of Exelon, Constellation has joint and several liability with Exelon to the IRS and certain state jurisdictions relating to the taxable periods prior to the separation. The TMA specifies that Constellation is liable for their share of taxes required to be paid by Exelon with respect to taxable periods prior to the separation to the extent Constellation would have been responsible for such taxes under the existing Exelon tax sharing agreement. As a result, Exelon recorded a receivable of $55 million in Current other assets in the Consolidated Balance Sheet for Constellation’s share of taxes for periods prior to the 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 $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 $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 June 30, 2022:

Operating Company(a)

Name of Plan:

ComEd

PECO

BGE

PHI

Pepco

DPL

ACE

Qualified Pension Plans:

Exelon Corporation Retirement Program

Exelon Corporation Pension Plan for Bargaining Unit Employees

Exelon Pension Plan

Pepco Holdings LLC Retirement Plan

Non-Qualified Pension Plans:

Exelon Corporation Supplemental Pension Benefit Plan and 2000 Excess Benefit Plan

Exelon Corporation Supplemental Management Retirement Plan

Constellation Energy Group, Inc. Senior Executive Supplemental Plan

Constellation Energy Group, Inc. Supplemental Pension Plan

Constellation Energy Group, Inc. Benefits Restoration Plan

Baltimore Gas & Electric Company Executive Benefit Plan

Baltimore Gas & Electric Company Manager Benefit Plan

Pepco Holdings LLC 2011 Supplemental Executive Retirement Plan

Conectiv Supplemental Executive Retirement Plan

Pepco Holdings LLC Combined Executive Retirement Plan

Atlantic City Electric Director Retirement Plan

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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

PHI

Pepco

DPL

ACE

OPEB Plans:

PECO Energy Company Retiree Medical Plan

Exelon Corporation Health Care Program

Exelon Corporation Employees’ Life Insurance Plan

Exelon Corporation Health Reimbursement Arrangement Plan

BGE Retiree Medical Plan

BGE Retiree Dental Plan

Exelon Employee Life Insurance Plan and Family Life Insurance Plan

Exelon Retiree Medical Plan of Constellation Energy Nuclear Group, LLC

Exelon Retiree Dental Plan of Constellation Energy Nuclear Group, LLC

Pepco Holdings LLC Welfare Plan for Retirees

__________

(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 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 Benefits				OPEB
	Three Months Ended June 30,				Three Months Ended June 30,
	2022		2021		2022		2021
Components of net periodic benefit cost:
Service cost	$	58	$	75	$	10	$	13
Interest cost	110		101		19		17
Expected return on assets	(205)		(210)		(25)		(25)
Amortization of:
Prior service cost (credit)	1		—		(5)		(7)
Actuarial loss	73		99		4		8


Net periodic benefit cost	$	37	$	65	$	3	$	6

	Pension Benefits				OPEB
	Six Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Components of net periodic benefit cost:
Service cost	$	119	$	148	$	20	$	26
Interest cost	220		202		38		35
Expected return on assets	(414)		(421)		(50)		(50)
Amortization of:
Prior service cost (credit)	2		1		(10)		(13)
Actuarial loss	149		199		8		14
Curtailment benefits	—		—		—		(1)

Net periodic benefit cost	$	76	$	129	$	6	$	11

The amounts below represent the Registrants' allocated pension and OPEB costs. For Exelon, the service cost component is included in Operating and maintenance expense and Property, plant, and equipment, net while the non-service cost components are included in Other, net and Regulatory assets. For the Utility Registrants, 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.

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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)	2022		2021		2022		2021
Exelon	$	40	$	71	$	82	$	140
ComEd	14		32		30		64
PECO	(2)		2		(4)		4
BGE	11		16		22		31
PHI	13		12		26		24
Pepco	2		2		4		3
DPL	1		1		2		1
ACE	3		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 plan for the three and six months ended June 30, 2022 and 2021, respectively.


	Three Months Ended June 30,				Six Months Ended June 30,
Savings Plan Matching Contributions	2022		2021		2022		2021
Exelon	$	23	$	23	$	43	$	43
ComEd	10		10		18		18
PECO	3		3		6		6
BGE	3		2		5		4
PHI	4		4		7		7
Pepco	1		1		2		2
DPL	1		1		2		2
ACE	1		1		1		1

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

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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

gas price volatility and have no direct earnings impact as the costs are fully recovered from customers through regulatory-approved recovery mechanisms. The following table provides a summary of the Utility Registrants’ primary derivative hedging instruments, listed by commodity and accounting treatment.


Registrant	Commodity	Accounting Treatment	Hedging Instrument
ComEd	Electricity	NPNS	Fixed price contracts based on all requirements in the IPA procurement plans.
	Electricity	Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability(a)	20-year floating-to-fixed energy swap contracts beginning June 2012 based on the renewable energy resource procurement requirements in the Illinois Settlement Legislation of approximately 1.3 million MWhs per year.
PECO	Electricity	NPNS	Fixed price contracts for default supply requirements through full requirements contracts.
	Gas	NPNS	Fixed price contracts to cover about 10% of planned natural gas purchases in support of projected firm sales.
BGE	Electricity	NPNS	Fixed price contracts for all SOS requirements through full requirements contracts.
	Gas	NPNS	Fixed price contracts for between 10-20% of forecasted system supply requirements for flowing (i.e., non-storage) gas for the November through March period.
Pepco	Electricity	NPNS	Fixed price contracts for all SOS requirements through full requirements contracts.
DPL	Electricity	NPNS	Fixed price contracts for all SOS requirements through full requirements contracts.
	Gas	NPNS	Fixed and index priced contracts through full requirements contracts.
		Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability(b)	Exchange traded future contracts for up to 50% of estimated monthly purchase requirements each month, including purchases for storage injections.
ACE	Electricity	NPNS	Fixed price contracts for all BGS requirements through full requirements contracts.

__________

(a)See Note 3 — Regulatory Matters of the 2021 Recast Form 10-K for additional information.

(b)The fair value of the DPL economic hedge is not material as of 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 June 30, 2022, the amount of cash collateral held with external counterparties by Exelon, ComEd, BGE, PHI, Pepco, DPL, and ACE was $781 million, $133 million, $194 million, $452 million, $87 million, $224 million, and $141 million, respectively, which is recorded in Other current liabilities in Exelon's, ComEd's, BGE's, PHI's, Pepco's, DPL's, and ACE's Consolidated Balance Sheets. The amount of cash collateral received from external counterparties

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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 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 June 30, 2022, they could have been required to post collateral to their counterparties of $37 million, $75 million, and $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 June 30, 2022 and December 31, 2021. ComEd had no commercial paper borrowings as of June 30, 2022 and December 31, 2021.


	Outstanding Commercial Paper as of				Average Interest Rate on Commercial Paper Borrowings as of
Commercial Paper Issuer	June 30, 2022		December 31, 2021		June 30, 2022		December 31, 2021
Exelon(a)	$	353	$	599	1.86	%	0.35	%

PECO	210		—		1.86	%	—	%
BGE	—		130		—	%	0.37	%
PHI(b)	43		469		1.85	%	0.35	%

Pepco	43		175		1.85	%	0.33	%
DPL	—		149		—	%	0.36	%
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 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:


Borrower	Aggregate Bank Commitment	Interest Rate
Exelon Corporate	900	SOFR plus 1.275	%
ComEd	1,000	SOFR plus 1.000	%
PECO	600	SOFR plus 0.900	%
BGE	600	SOFR plus 0.900	%
Pepco	300	SOFR plus 1.075	%
DPL	300	SOFR plus 1.000	%
ACE	300	SOFR plus 1.075	%

See Note 15 — Debt and Credit Agreements of the 2021 Recast Form 10-K for additional information on the Registrants' credit facilities.

Short-Term Loan Agreements

On March 23, 2017, Exelon Corporate entered into a term loan agreement for $500 million. The loan agreement was renewed 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 which commenced on July 24, 2022. All indebtedness pursuant to the loan agreement is unsecured.

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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 six months ended June 30, 2022, the following long-term debt was issued:

Company

Type

Interest Rate

Maturity

Amount

Use of Proceeds

Exelon

SMBC Term Loan Agreement

SOFR plus 0.65%

July 21, 2023

$300

Fund a cash payment to Constellation and for general corporate purposes.

Exelon

U.S. Bank Term Loan Agreement

SOFR plus 0.65%

July 21, 2023

300

Fund a cash payment to Constellation and for general corporate purposes.

Exelon

PNC Term Loan Agreement

SOFR plus 0.65%

July 24, 2023

250

Fund a cash payment to Constellation and for general corporate purposes.

Exelon

Notes(b)

2.75%

March 15, 2027

650

Repay existing indebtedness and for general corporate purposes.

Exelon

Notes(b)

3.35%

March 15, 2032

650

Repay existing indebtedness and for general corporate purposes.

Exelon

Notes(b)

4.10%

March 15, 2052

700

Repay existing indebtedness and for general corporate purposes.

ComEd

First Mortgage Bonds, Series 132

3.15%

March 15, 2032

300

Repay outstanding commercial paper obligations and to fund other general corporate purposes.

ComEd

First Mortgage Bonds, Series 133

3.85%

March 15, 2052

450

Repay outstanding commercial paper obligations and to fund other general corporate purposes.

PECO

First and Refunding Mortgage Bonds

4.60%

May 15, 2052

350

Refinance existing indebtedness and for general corporate purposes.

BGE

Notes

4.55%

June 1, 2052

500

Repay outstanding commercial paper obligations, repay existing indebtedness, and for general corporate purposes.

Pepco(a)

First Mortgage Bonds

3.97%

March 24, 2052

400

Repay existing indebtedness and for general corporate purposes.

DPL

First Mortgage Bonds

3.06%

February 15, 2052

125

Repay existing indebtedness and for general corporate purposes.

ACE

First Mortgage Bonds

2.27%

February 15, 2032

Repay existing indebtedness and for general corporate purposes.

ACE

First Mortgage Bonds

3.06%

February 15, 2052

150

Repay existing indebtedness and for general corporate purposes.

__________

(a)On March 24, 2022, 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 15 — Debt and Credit Agreements of the 2021 Recast Form 10-K for additional information. In connection with the separation, on January 31, 2022, Exelon Corporate received cash from Generation of $258 million to settle the intercompany loan.

Debt Covenants

As of June 30, 2022, the Registrants are in compliance with debt covenants.

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Fair Value of Financial Assets and Liabilities

11. Fair Value of Financial Assets and Liabilities (All Registrants)

Exelon measures and classifies fair value measurements in accordance with the hierarchy as defined by GAAP. The hierarchy prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:

•Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that the Registrants have the ability to liquidate as of the reporting date.

•Level 2 - inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

•Level 3 - unobservable inputs, such as internally developed pricing models or third-party valuations for the asset or liability due to little or no market activity for the asset or liability.

Fair Value of Financial Liabilities Recorded at Amortized Cost

The following tables present the carrying amounts and fair values of the Registrants’ short-term liabilities, long-term debt, and trust preferred securities (long-term debt to financing trusts or junior subordinated debentures) as of June 30, 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.


	June 30, 2022								December 31, 2021
	Carrying Amount		Fair Value						Carrying Amount		Fair Value
			Level 2		Level 3		Total				Level 2		Level 3		Total
Long-Term Debt, including amounts due within one year(a)
Exelon	$	36,294	$	30,960	$	2,315	$	33,275	$	32,902	$	34,897	$	2,217	$	37,114
ComEd	10,516		9,609		—		9,609		9,773		11,305		—		11,305
PECO	4,192		3,772		50		3,822		4,197		4,740		50		4,790
BGE	4,456		4,096		—		4,096		3,961		4,406		—		4,406
PHI	8,027		4,853		2,265		7,118		7,547		5,970		2,167		8,137
Pepco	3,642		2,465		1,104		3,569		3,445		3,201		975		4,176
DPL	1,938		1,210		503		1,713		1,810		1,426		552		1,978
ACE	1,757		954		658		1,612		1,582		1,091		641		1,732
Long-Term Debt to Financing Trusts
Exelon	$	390	$	—	$	398	$	398	$	390	$	—	$	470	$	470
ComEd	205		—		209		209		205		—		248		248
PECO	184		—		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 15 - Debt and Credit Agreements of the 2021 Recast Form 10-K for unamortized debt issuance costs, unamortized debt discount and premium, net, and purchase accounting fair value adjustments and Note 10 - Leases of the 2021 Recast Form 10-K for finance lease liabilities.

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Fair Value of Financial Assets and Liabilities

Recurring Fair Value Measurements

The following tables present assets and liabilities measured and recorded at fair value in the Registrants' Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of June 30, 2022 and December 31, 2021:

Exelon


	As of June 30, 2022						As of December 31, 2021
	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	1,319	$	—	$	—	$	1,319	$	524	$	—	$	—	$	524
Rabbi trust investments
Cash equivalents	63		—		—		63		60		—		—		60
Mutual funds	52		—		—		52		60		—		—		60
Fixed income	—		8		—		8		—		10		—		10
Life insurance contracts	—		59		38		97		—		61		37		98
Rabbi trust investments subtotal	115		67		38		220		120		71		37		228
Mark-to-market derivative assets	—		—		15		15		—		—		—		—
Total assets	1,434		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 $177 million and $464 million as of June 30, 2022 and December 31, 2021, respectively, and restricted cash of $340 million and $49 million as of June 30, 2022 and December 31, 2021, respectively, and includes long-term restricted cash of $59 million and $44 million as of June 30, 2022 and December 31, 2021, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets.

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Fair Value of Financial Assets and Liabilities

ComEd, PECO, and BGE


	ComEd								PECO								BGE
As of June 30, 2022	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	409	$	—	$	—	$	409	$	11	$	—	$	—	$	11	$	318	$	—	$	—	$	318
Rabbi trust investments

Mutual funds	—		—		—		—		9		—		—		9		7		—		—		7
Life insurance contracts	—		—		—		—		—		16		—		16		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		9		16		—		25		7		—		—		7
Mark-to-market derivative assets(b)	—		—		15		15		—		—		—		—		—		—		—		—
Total assets	409		—		15		424		20		16		—		36		325		—		—		325
Liabilities
Mark-to-market derivative liabilities(b)	—		—		(103)		(103)		—		—		—		—		—		—		—		—
Deferred compensation obligation	—		(8)		—		(8)		—		(7)		—		(7)		—		(4)		—		(4)
Total liabilities	—		(8)		(103)		(111)		—		(7)		—		(7)		—		(4)		—		(4)
Total net assets (liabilities)	$	409	$	(8)	$	(88)	$	313	$	20	$	9	$	—	$	29	$	325	$	(4)	$	—	$	321


	ComEd								PECO								BGE
As of December 31, 2021	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
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 assets	237		—		—		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 $21 million and $105 million as of June 30, 2022 and December 31, 2021, respectively, and restricted cash of $133 million and $42 million as of June 30, 2022 and December 31, 2021, respectively, and includes long-term restricted cash of $59 million and $43 million as of June 30, 2022 and December 31, 2021, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. PECO excludes cash of $21 million and $35 million as of June 30, 2022 and December 31, 2021, respectively. BGE excludes cash of $36 million and $51 million as of June 30, 2022 and December 31, 2021, respectively, and restricted cash of $205 million and $4 million as of 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 $103 million, respectively, as of 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.

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Fair Value of Financial Assets and Liabilities

PHI, Pepco, DPL, and ACE


	As of June 30, 2022								As of December 31, 2021
PHI	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	557	$	—	$	—	$	557	$	110	$	—	$	—	$	110
Rabbi trust investments
Cash equivalents	60		—		—		60		59		—		—		59
Mutual funds	11		—		—		11		14		—		—		14
Fixed income	—		8		—		8		—		10		—		10
Life insurance contracts	—		22		37		59		—		27		35		62
Rabbi trust investments subtotal	71		30��		37		138		73		37		35		145
Total assets	628		30		37		695		183		37		35		255
Liabilities
Deferred compensation obligation	—		(14)		—		(14)		—		(18)		—		(18)



Total liabilities	—		(14)		—		(14)		—		(18)		—		(18)
Total net assets	$	628	$	16	$	37	$	681	$	183	$	19	$	35	$	237


	Pepco								DPL								ACE
As of June 30, 2022	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	115	$	—	$	—	$	115	$	223	$	—	$	—	$	223	$	218	$	—	$	—	$	218




Rabbi trust investments
Cash equivalents	59		—		—		59		—		—		—		—		—		—		—		—

Life insurance contracts	—		22		37		59		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	59		22		37		118		—		—		—		—		—		—		—		—
Total assets	174		22		37		233		223		—		—		223		218		—		—		218
Liabilities
Deferred compensation obligation	—		(1)		—		(1)		—		—		—		—		—		—		—		—



Total liabilities	—		(1)		—		(1)		—		—		—		—		—		—		—		—
Total net assets	$	174	$	21	$	37	$	232	$	223	$	—	$	—	$	223	$	218	$	—	$	—	$	218

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Fair Value of Financial Assets and Liabilities


	Pepco								DPL								ACE
As of December 31, 2021	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	31	$	—	$	—	$	31	$	43	$	—	$	—	$	43	$	—	$	—	$	—	$	—
Rabbi trust investments
Cash equivalents	58		—		—		58		—		—		—		—		—		—		—		—


Life insurance contracts	—		27		35		62		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	58		27		35		120		—		—		—		—		—		—		—		—
Total assets	89		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 $60 million and $100 million as of June 30, 2022 and December 31, 2021, respectively, and restricted cash of $2 million and $3 million as of June 30, 2022 and December 31, 2021, respectively. Pepco excludes cash of $14 million and $34 million as of June 30, 2022 and December 31, 2021, respectively, and restricted cash of $2 million and $3 million as of June 30, 2022 and December 31, 2021, respectively. DPL excludes cash of $26 million and $28 million as of June 30, 2022 and December 31, 2021, respectively. ACE excludes cash of $15 million and $29 million as of June 30, 2022 and December 31, 2021, respectively.

Reconciliation of Level 3 Assets and Liabilities

The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis during the three and six months ended June 30, 2022 and 2021:



	Exelon		ComEd			PHI and Pepco
Three Months Ended June 30, 2022	Total		Mark-to-Market Derivatives			Life Insurance Contracts
Balance as of April 1, 2022	$	(107)	$	(144)		$	36
Total realized / unrealized gains
Included in net income(a)	1		—			1


Included in regulatory assets/liabilities	56		56		(b)	—








Balance at June 30, 2022	$	(50)	$	(88)	(c)	$	37
The amount of total gains included in income attributed to the change in unrealized gains related to assets and liabilities as of June 30, 2022	$	1	$	—		$	1

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Fair Value of Financial Assets and Liabilities



	Exelon		ComEd			PHI and Pepco
Three Months Ended June 30, 2021	Total		Mark-to-Market Derivatives			Life Insurance Contracts
Balance as of April 1, 2021	$	(260)	$	(295)		$	35
Total realized / unrealized gains
Included in net income(a)	1		—			1

Included in regulatory assets	30		30		(b)	—

Purchases, sales, and settlements



Settlements	(2)		—			(2)


Balance as of June 30, 2021	$	(231)	$	(265)		$	34
The amount of total gains included in income attributed to the change in unrealized gains related to assets and liabilities as of June 30, 2021	$	1	$	—		$	1


	Exelon		ComEd			PHI and Pepco
Six months ended June 30, 2022	Total		Mark-to-Market Derivatives			Life Insurance Contracts
Balance as of January 1, 2022	$	(182)	$	(219)		$	35
Total realized / unrealized gains
Included in net income(a)	2		—			2


Included in regulatory assets/liabilities	131		131		(b)	—







Transfers out of Level 3	(1)		—			—
Balance as of June 30, 2022	$	(50)	$	(88)	(c)	$	37
The amount of total gains included in income attributed to the change in unrealized gains related to assets and liabilities as of June 30, 2022	$	2	$	—		$	2


	Exelon		ComEd			PHI and Pepco
Six Months Ended June 30, 2021	Total		Mark-to-Market Derivatives			Life Insurance Contracts
Balance as of January 1, 2021	$	(267)	$	(301)		$	34
Total realized / unrealized gains
Included in net income(a)	2		—			2


Included in regulatory assets	36		36		(b)	—

Purchases, sales, and settlements



Settlements	(2)		—			(2)


Balance as of June 30, 2021	$	(231)	$	(265)		$	34
The amount of total gains included in income attributed to the change in unrealized gain related to assets and liabilities as of June 30, 2021	$	2	$	—		$	2

__________

(a)Classified in Operating and maintenance expense in the Consolidated Statements of Operations and Comprehensive Income.

(b)Includes $59 million of increases in fair value and a decrease for realized gains due to settlements of $3 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended June 30, 2022. Includes $25 million of increases in fair value and an increase for realized losses due to settlements of $5 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended June 30, 2021. Includes $128 million of increases in fair value and an increase for realized losses due to settlements of $3 million recorded in purchase power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the six months ended June 30, 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.

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Fair Value of Financial Assets and Liabilities

Valuation Techniques Used to Determine Fair Value

Exelon’s valuation techniques used to measure the fair value of the assets and liabilities shown in the tables below are in accordance with the policies discussed in Note 16 — Fair Value of Financial Assets and Liabilities of the 2021 Recast Form 10-K.

Mark-to-Market Derivatives (Exelon and ComEd)

The table below discloses the significant unobservable inputs to the forward curve used to value mark-to-market derivatives.


Type of trade	Fair Value as of June 30, 2022		Fair Value as of December 31, 2021		Valuation Technique	Unobservable Input	2022 Range & Arithmetic Average				2021 Range & Arithmetic Average
Mark-to-market derivatives	$	(88)	$	(219)	Discounted Cash Flow	Forward power price(a)	$30.54	-	$89.78	$46.33	$28.65	-	$47.10	$33.96

________

(a)An increase to the forward power price would increase the fair value.

12. Commitments and Contingencies (All Registrants)

The following is an update to the current status of commitments and contingencies set forth in Note 17 — Commitments and Contingencies of the 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 June 30, 2022:


Description	Exelon		PHI		Pepco		DPL		ACE
Total commitments	$	513	$	320	$	120	$	89	$	111
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, DPL has committed to conducting three RFPs to procure up to a total of 120 MWs of wind RECs for the purpose of meeting Delaware's renewable portfolio standards. DPL has conducted two of the three wind REC RFPs. The first 40 MW wind REC tranche was conducted in 2017 and did not result in a purchase agreement. The second 40 MW wind REC tranche was conducted in 2018 and resulted in a proposed REC purchase agreement that was approved by the DEPSC in 2019. The RFP for the third and final 40 MW wind REC tranche is under way and bids will be evaluated in the third quarter of 2022, with a potential award in the fourth quarter of 2022.

Table of Contents

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 12 — Commitments and Contingencies

Commercial Commitments (All Registrants). The Registrants’ commercial commitments as of June 30, 2022, representing commitments potentially triggered by future events were as follows:


			Expiration within
	Total		2022		2023		2024		2025		2026		2027 and beyond
Exelon
Letters of credit	$	17	$	8	$	9	$	—	$	—	$	—	$	—
Surety bonds(a)	185		144		39		2		—		—		—
Financing trust guarantees	378		—		—		—		—		—		378
Guaranteed lease residual values(b)	30		—		2		6		6		5		11
Total commercial commitments	$	610	$	152	$	50	$	8	$	6	$	5	$	389

ComEd
Letters of credit	$	10	$	4	$	6	$	—	$	—	$	—	$	—
Surety bonds(a)	16		9		5		2		—		—		—
Financing trust guarantees	200		—		—		—		—		—		200
Total commercial commitments	$	226	$	13	$	11	$	2	$	—	$	—	$	200

PECO
Letters of credit	$	1	$	—	$	1	$	—	$	—	$	—	$	—
Surety bonds(a)	3		1		2		—		—		—		—
Financing trust guarantees	178		—		—		—		—		—		178
Total commercial commitments	$	182	$	1	$	3	$	—	$	—	$	—	$	178

BGE
Letters of credit	$	2	$	2	$	—	$	—	$	—	$	—	$	—
Surety bonds(a)	2		1		1		—		—		—		—
Total commercial commitments	$	4	$	3	$	1	$	—	$	—	$	—	$	—

PHI

Surety bonds(a)	$	95	$	76	$	19	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	30		—		2		6		6		5		11
Total commercial commitments	$	125	$	76	$	21	$	6	$	6	$	5	$	11

Pepco

Surety bonds(a)	$	84	$	71	$	13	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	10		—		1		2		2		2		3
Total commercial commitments	$	94	$	71	$	14	$	2	$	2	$	2	$	3

DPL

Surety bonds(a)	$	7	$	3	$	4	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	13		—		—		3		3		2		5
Total commercial commitments	$	20	$	3	$	4	$	3	$	3	$	2	$	5

ACE
Surety bonds(a)	$	4	$	2	$	2	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	7		—		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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(Dollars in millions, except per share data, unless otherwise noted)

Note 12 — Commitments and Contingencies

(b)Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The lease term associated with these assets ranges from 1 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $74 million guaranteed by Exelon and PHI, of which $24 million, $31 million, and $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 federal and state environmental laws, the Registrants are generally liable for the costs of remediating environmental contamination of property now or formerly owned by them and of property contaminated by hazardous substances generated by them. The Registrants own or lease a number of real estate parcels, including parcels on which their operations or the operations of others may have resulted in contamination by substances that are considered hazardous under environmental laws. In addition, the Registrants are currently involved in a number of proceedings relating to sites where hazardous substances have been deposited and may be subject to additional proceedings in the future. Unless otherwise disclosed, the Registrants cannot reasonably estimate whether they will incur significant liabilities for additional investigation and remediation costs at these or additional sites identified by the Registrants, environmental agencies or others, or whether such costs will be recoverable from third parties, including customers. Additional costs could have a material, unfavorable impact on the Registrants' financial statements.

MGP Sites (All Registrants). ComEd, PECO, BGE, and DPL have identified sites where former MGP or gas purification activities have or may have resulted in actual site contamination. For almost all of 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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(Dollars in millions, except per share data, unless otherwise noted)

Note 12 — Commitments and Contingencies

As of 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:


	June 30, 2022				December 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
Exelon	$	347	$	299	$	352	$	303
ComEd	274		273		279		279
PECO	21		20		22		20
BGE	7		6		6		4
PHI	42		—		42		—
Pepco	40		—		40		—
DPL	1		—		1		—
ACE	1		—		1		—

Benning Road Site (Exelon, PHI, and Pepco). In September 2010, PHI received a letter from EPA identifying the Benning Road site as one of six land-based sites potentially contributing to contamination of the lower Anacostia River. A portion of the site, which is owned by Pepco, was formerly the location of an electric generating facility owned by Pepco subsidiary, Pepco Energy Services (PES), which became a part of Generation, following the 2016 merger between PHI and Exelon. This generating facility was deactivated in June 2012. The remaining portion of the site consists of a Pepco transmission and distribution service center that remains in operation. In December 2011, the U.S. District Court for the District of Columbia approved a Consent Decree entered into by Pepco and Pepco Energy Services (hereinafter "Pepco Entities") with the DOEE, which requires the Pepco Entities to conduct a Remedial Investigation and Feasibility Study (RI/FS) for the Benning Road site and an approximately 10 to 15-acre portion of the adjacent Anacostia River. The purpose of this RI/FS is to define the nature and extent of contamination from the Benning Road site and to evaluate remedial alternatives.

Pursuant to an internal agreement between the Pepco Entities, since 2013, Pepco has performed the work required by the Consent Decree and has been reimbursed for that work by an agreed upon allocation of costs between the Pepco Entities. In September 2019, the Pepco Entities issued a draft “final” RI report which DOEE approved on February 3, 2020. The Pepco Entities are 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) 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.

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

Note 12 — Commitments and Contingencies

environmental certainty, is less costly, and allows for site specific remediation plans already underway, including the plan for the Benning Road site to proceed to conclusion.

On July 15, 2022, Pepco received a letter from the District of Columbia's Office of the Attorney General (District) 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.

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

Note 12 — Commitments and Contingencies

appointed interim lead plaintiffs in the federal cases which consisted of counsel for three of the four federal cases. These plaintiffs filed a consolidated complaint on January 5, 2021. CUB also filed its own complaint against ComEd only on the same day. The remaining federal case, Potter, et al. v. Exelon et al, differed from the other lawsuits as it named additional individual defendants not named in the consolidated complaint. However, the Potter plaintiffs voluntarily dismissed their complaint without prejudice on April 5, 2021. ComEd and Exelon moved to dismiss the consolidated class action complaint and CUB’s complaint on February 4, 2021 and briefing was completed on March 22, 2021. On March 25, 2021, the parties agreed, along with state court plaintiffs, discussed below, to jointly engage in mediation. The parties participated in a one-day mediation on June 7, 2021 but no settlement was reached. On September 9, 2021, the federal court granted Exelon’s and ComEd’s motion to dismiss and dismissed the plaintiffs’ and CUB’s federal law claim with prejudice. The federal court also dismissed the related state law claims made by the federal plaintiffs and CUB on jurisdictional grounds. Plaintiffs appealed dismissal of the federal law claim to the Seventh Circuit Court of Appeals. Plaintiffs and CUB also refiled their state law claims in state court and moved to consolidate them with the already pending consumer state court class action, discussed below. Plaintiffs' opening appeal brief 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. Oral argument was 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 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 September 30, 2022 and reset the next court status for August 15, 2022.

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

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) 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 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 requested a further extension of the stay until September 14, 2022, which the court 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, including 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 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). 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 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 June 30, 2022	Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items(a)		Foreign Currency Items		Total
Balance at March 31, 2022	$	—	$	(713)	$	—	$	(713)
OCI before reclassifications	—		2		—		2
Amounts reclassified from AOCI	—		10		—		10
Net current-period OCI	—		12		—		12
Balance at June 30, 2022	$	—	$	(701)	$	—	$	(701)


Three Months Ended June 30, 2021	Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items(a)		Foreign Currency Items		Total
Balance at March 31, 2021	$	(5)	$	(3,319)	$	(22)	$	(3,346)
OCI before reclassifications	—		—		2		2
Amounts reclassified from AOCI	—		55		—		55
Net current-period OCI	—		55		2		57
Balance at June 30, 2021	$	(5)	$	(3,264)	$	(20)	$	(3,289)


Six Months Ended June 30, 2022	Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items(a)		Foreign Currency Items		Total
Balance at December 31, 2021	$	(6)	$	(2,721)	$	(23)	$	(2,750)
Separation of Constellation	6		1,994		23		2,023
OCI before reclassifications	—		2		—		2
Amounts reclassified from AOCI	—		24		—		24
Net current-period OCI	—		26		—		26
Balance at June 30, 2022	$	—	$	(701)	$	—	$	(701)

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

Note 13 — Changes in Accumulated Other Comprehensive Income


Six Months Ended June 30, 2021	Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items(a)		Foreign Currency Items		Total
Balance at December 31, 2020	$	(5)	$	(3,372)	$	(23)	$	(3,400)
OCI before reclassifications	—		(2)		3		1
Amounts reclassified from AOCI	—		110		—		110
Net current-period OCI	—		108		3		111
Balance at June 30, 2021	$	(5)	$	(3,264)	$	(20)	$	(3,289)

__________

(a)This AOCI component is included in the computation of net periodic pension and OPEB cost. Additionally, as of February 1, 2022, in connection with the separation, Exelon's pension and OPEB plans were remeasured. See Note 8 — Retirement Benefits for additional information. See Exelon's Statements of Operations and Comprehensive Income for individual components of AOCI.

The following table presents income tax benefit (expense) allocated to each component of Exelon's other comprehensive income (loss):


	Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
Pension and non-pension postretirement benefit plans:
Prior service benefit reclassified to periodic benefit cost	$	—	$	1	$	—	$	2
Actuarial loss reclassified to periodic benefit cost	(3)		(19)		(8)		(38)
Pension and non-pension postretirement benefit plans valuation adjustment	(1)		(1)		—		(1)

14. Supplemental Financial Information (All Registrants)

Supplemental Statement of Operations Information

The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Operations and Comprehensive Income:

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Note 14 — Supplemental Financial Information


	Taxes other than income taxes
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended June 30, 2022
Utility taxes(a)	$	203	$	71	$	39	$	20	$	73	$	67	$	5	$	1
Property	94		10		4		46		33		23		10		—
Payroll	28		7		5		4		7		1		1		1

Three Months Ended June 30, 2021
Utility taxes(a)	$	184	$	61	$	32	$	20	$	71	$	65	$	5	$	—
Property	86		8		4		43		31		20		10		1
Payroll	32		6		4		5		7		1		1		1

Six Months Ended June 30, 2022
Utility taxes(a)	$	424	$	149	$	77	$	47	$	151	$	137	$	12	$	2
Property	188		20		9		92		67		46		20		1
Payroll	64		13		8		9		14		3		2		2

Six Months Ended June 30, 2021
Utility taxes(a)	$	377	$	121	$	66	$	45	$	145	$	132	$	11	$	1
Property	173		16		9		85		63		42		19		1
Payroll	64		13		8		9		14		3		3		2

_________

(a)The Registrants' utility taxes represent municipal and state utility taxes and gross receipts taxes related to their operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.



	Other, Net
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended June 30, 2022
AFUDC — Equity	$	38	$	9	$	8	$	6	$	15	$	11	$	2	$	2
Non-service net periodic benefit cost	16		—		—		—		—		—		—		—


Three Months Ended June 30, 2021
AFUDC — Equity	$	34	$	9	$	6	$	7	$	12	$	10	$	1	$	1
Non-service net periodic benefit cost	26		—		—		—		—		—		—		—



Six Months Ended June 30, 2022

AFUDC — Equity	$	74	$	17	$	15	$	12	$	30	$	22	$	4	$	4
Non-service net periodic benefit cost	33		—		—		—		—		—		—		—


Six Months Ended June 30, 2021

AFUDC — Equity	$	64	$	13	$	12	$	14	$	25	$	20	$	3	$	2
Non-service net periodic benefit cost	46		—		—		—		—		—		—		—

Supplemental Cash Flow Information

The following tables provide additional information about material items recorded in the Registrants' Consolidated Statements of Cash Flows.

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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


	Depreciation and amortization
	Exelon(a)		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Six Months Ended June 30, 2022
Property, plant, and equipment(b)	$	1,376	$	511	$	177	$	235	$	335	$	145	$	92	$	83
Amortization of regulatory assets(b)	357		138		8		87		124		68		21		35
Amortization of intangible assets, net(b)	8		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(c)	3		—		—		—		—		—		—		—
Nuclear fuel(d)	66		—		—		—		—		—		—		—
ARO accretion(e)	44		—		—		—		—		—		—		—
Total depreciation, amortization, and accretion	$	1,854	$	649	$	185	$	322	$	459	$	213	$	113	$	118

Six Months Ended June 30, 2021
Property, plant, and equipment(b)	$	3,043	$	480	$	165	$	215	$	309	$	135	$	84	$	76
Amortization of regulatory assets(b)	291		109		8		78		95		64		20		11
Amortization of intangible assets, net(b)	29		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(c)	13		—		—		—		—		—		—		—
Nuclear fuel(d)	549		—		—		—		—		—		—		—
ARO accretion(e)	255		—		—		—		—		—		—		—
Total depreciation, amortization, and accretion	$	4,180	$	589	$	173	$	293	$	404	$	199	$	104	$	87

__________

(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 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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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 14 — Supplemental Financial Information


	Other non-cash operating activities
	Exelon(a)		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Six Months Ended June 30, 2022
Pension and non-pension postretirement benefit costs	$	86	$	30	$	(4)	$	22	$	26	$	4	$	2	$	6
Allowance for credit losses	96		29		21		18		29		16		6		7
Other decommissioning-related activity	36		—		—		—		—		—		—		—
Energy-related options	60		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(b)	(27)		(75)		(6)		32		22		7		3		12


Long-term incentive plan	40		—		—		—		—		—		—		—


Amortization of operating ROU asset	38		1		—		14		14		4		4		2


AFUDC — Equity	(74)		(17)		(15)		(12)		(30)		(22)		(4)		(4)

Six Months Ended June 30, 2021
Pension and non-pension postretirement benefit costs	$	196	$	64	$	4	$	29	$	24	$	3	$	1	$	5
Allowance for credit losses	100		24		17		4		9		5		2		2
Other decommissioning-related activity	(636)		—		—		—		—		—		—		—
Energy-related options	20		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(b)	(176)		(64)		(17)		(8)		(88)		(46)		(19)		(23)


Long-term incentive plan	62		—		—		—		—		—		—		—


Amortization of operating ROU asset	83		1		—		15		14		3		5		2


AFUDC — Equity	(64)		(13)		(12)		(14)		(25)		(20)		(3)		(2)

__________

(a)Exelon's 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 2021 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.


	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
June 30, 2022
Cash and cash equivalents	$	816	$	120	$	23	$	354	$	278	$	14	$	26	$	233
Restricted cash and cash equivalents	961		384		9		205		341		117		223		—
Restricted cash included in other long-term assets	59		59		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents	$	1,836	$	563	$	32	$	559	$	619	$	131	$	249	$	233

December 31, 2021
Cash and cash equivalents	$	672	$	131	$	36	$	51	$	136	$	34	$	28	$	29
Restricted cash and cash equivalents	321		210		8		4		77		34		43		—
Restricted cash included in other long-term assets	44		43		—		—		—		—		—		—
Cash, restricted cash, and cash equivalents from discontinued operations	582		—		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents	$	1,619	$	384	$	44	$	55	$	213	$	68	$	71	$	29

June 30, 2021
Cash and cash equivalents	$	1,578	$	71	$	376	$	368	$	61	$	17	$	17	$	11
Restricted cash and cash equivalents	379		240		8		3		42		33		5		3
Restricted cash included in other long-term assets	52		43		—		—		9		—		—		9
Total cash, restricted cash, and cash equivalents(a)	$	2,009	$	354	$	384	$	371	$	112	$	50	$	22	$	23

December 31, 2020
Cash and cash equivalents	$	432	$	83	$	19	$	144	$	111	$	30	$	15	$	17
Restricted cash and cash equivalents	349		279		7		1		39		35		—		3
Restricted cash included in other long-term assets	53		43		—		—		10		—		—		10
Cash, restricted cash, and cash equivalents from discontinued operations	332		—		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents	$	1,166	$	405	$	26	$	145	$	160	$	65	$	15	$	30

__________

(a)Exelon's amounts include amounts related to Generation prior to the separation. See Note 2 — Discontinued Operations for additional information.

For additional information on restricted cash see Note 1 — Significant Accounting Policies of the 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 expenses
	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
June 30, 2022
Compensation-related accruals(a)	$	428	$	109	$	57	$	54	$	82	$	26	$	16	$	13
Taxes accrued	243		94		60		31		84		57		12		11
Interest accrued	331		124		40		44		59		31		9		14

December 31, 2021
Compensation-related accruals(a)	$	596	$	155	$	77	$	78	$	113	$	35	$	20	$	17
Taxes accrued	253		94		14		53		96		88		9		11
Interest accrued	297		116		41		44		52		28		8		11

__________

(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 June 30,				Six Months Ended June 30,
	2022		2021		2022		2021
ComEd(a)	$	—	$	78	$	59	$	163
PECO(b)	—		41		33		83
BGE(c)	—		58		18		130
PHI	—		77		51		176
Pepco(d)	—		55		39		130
DPL(e)	—		17		10		37
ACE(f)	—		5		2		9

__________

(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 affiliates								Capitalized costs
	Three Months Ended June 30,				Six Months Ended June 30,				Three Months Ended June 30,				Six Months Ended June 30,
	2022		2021		2022		2021		2022		2021		2022		2021
Exelon
BSC									$	139	$	114	$	344	$	249
PHISCO									21		17		40		36
ComEd
BSC	$	80	$	72	$	165	$	143	67		45		152		102
PECO
BSC	47		40		96		80		20		17		56		44
BGE
BSC	51		45		102		88		22		20		60		43
PHI
BSC	46		37		96		76		30		32		76		60
PHISCO	—		—		—		—		21		17		40		36
Pepco
BSC	27		23		56		45		11		13		28		25
PHISCO	29		28		58		57		8		7		16		15

DPL
BSC	17		15		35		29		9		10		23		19
PHISCO	25		24		49		49		7		5		13		11

ACE
BSC	14		12		29		24		10		8		25		15
PHISCO	22		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:

June 30, 2022


				Receivables from affiliates:
	Payables to affiliates:			ComEd			PECO			BGE			Pepco			DPL			ACE			BSC			PHISCO			Other			Total
ComEd					$	—		$	—		$	—		$	—		$	—		$	57		$	—		$	8		$	65
PECO		$	—					—			—			—			—			25			—			4			29
BGE		—			—						—			—			—			28			—			2			30
PHI		—			—			—			—			—			—			5			—			10			15
Pepco		—			—			—						—			1			14			13			1			29
DPL		—			—			—			9						—			9			10			1			29
ACE		—			—			—			—			—						9			10			1			20
Other		3			—			—			—			—			—			—			—						3
Total		$	3		$	—		$	—		$	9		$	—		$	1		$	147		$	33		$	27		$	220

December 31, 2021


				Receivables from affiliates:
	Payables to affiliates:			ComEd			PECO			BGE			Pepco			DPL			ACE			Generation			BSC			PHISCO			Other			Total
ComEd					$	—		$	—		$	—		$	—		$	—		$	41		$	71		$	—		$	9		$	121
PECO		$	—					—			—			—			—			30			36			—			4			70
BGE		—			—						—			—			—			4			41			—			3			48
PHI		—			1			—			—			—			1			—			5			—			9			16
Pepco		—			—			1						1			1			20			21			12			3			59
DPL		—			—			—			—						—			4			17			11			1			33
ACE		—			—			—			—			—						7			13			9			2			31
Generation		13			—			—			—			—			—						102			—			16			131
Other		3			—			—			—			—			—			11			—			—						14
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 June 30, 2022 and in noncurrent Receivables from affiliates as of December 31, 2021. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements of the 2021 Recast Form 10-K for additional information.

Long-term debt to financing trusts

The following table presents Long-term debt to financing trusts:

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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


	June 30, 2022						December 31, 2021
	Exelon		ComEd		PECO		Exelon		ComEd		PECO
ComEd Financing III	$	206	$	205	$	—	$	206	$	205	$	—
PECO Trust III	81		—		81		81		—		81
PECO Trust IV	103		—		103		103		—		103
Total	$	390	$	205	$	184	$	390	$	205	$	184

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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 June 30, 2022 compared to the same period in 2021. For additional information regarding the financial results for the three and six months ended June 30, 2022 and 2021 see the discussions of Results of Operations by Registrant.


	Three Months Ended June 30,				Favorable (Unfavorable) Variance		Six Months Ended June 30,				Favorable (Unfavorable) Variance
	2022		2021				2022		2021
Exelon	$	465	$	326	$	139	$	946	$	851	$	95
ComEd	227		192		35		415		390		25
PECO	133		104		29		339		271		68
BGE	37		45		(8)		234		254		(20)
PHI	100		141		(41)		230		269		(39)
Pepco	70		75		(5)		116		134		(18)
DPL	21		30		(9)		77		86		(9)
ACE	11		37		(26)		37		51		(14)
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 June 30, 2022 Compared to Three Months Ended June 30, 2021. Net income attributable to common shareholders from continuing operations increased by $139 million and diluted

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earnings per average common share from continuing operations increased to $0.47 in 2022 from $0.33 in 2021 primarily due to:

•Higher electric distribution earnings from higher allowed electric distribution ROE due to an increase in treasury rates and higher rate base at ComEd;

•The favorable impacts of rate increases at PECO, BGE, and PHI; and

•Lower BSC costs, which were previously allocated to Generation but do not qualify as expenses of the discontinued operations per the accounting rules. Such costs, on a pre-tax basis, were $99 million for the three months ended June 30, 2021.

The increases were partially offset by:

•The absence of favorable weather and volume as a result of the CIP at ACE;

•Higher depreciation expense at BGE and PHI;

•Higher credit loss expense at PHI; and

•Higher interest expense at Exelon Corporate.

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 $206 million for the six months ended 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.

The following tables 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 June 30, 2022 compared to the same period in 2021.



	Three Months Ended June 30,
	2022				2021
(In millions, except per share data)			Earnings per Diluted Share				Earnings per Diluted Share
Net Income Attributable to Common Shareholders from Continuing Operations	$	465	$	0.47	$	326	$	0.33
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $1)	—		—		3		—
Cost Management Program (net of taxes of $0)	—		—		1		—
COVID-19 Direct Costs (net of taxes of $1)(a)	—		—		4		—
Acquisition Related Costs (net of taxes of $1)(b)	—		—		2		—
ERP System Implementation Costs (net of taxes $1)(c)	—		—		2		—
Separation Costs (net of taxes of $4 and $6, respectively)(d)	10		0.01		10		0.01
Income Tax-Related Adjustments (entire amount represents tax expense)(e)	(43)		(0.04)		—		—
Adjusted (non-GAAP) Operating Earnings	$	433	$	0.44	$	348	$	0.36


	Six Months Ended June 30,
	2022				2021
(In millions, except per share data)			Earnings per Diluted Share				Earnings per Diluted Share
Net Income Attributable to Common Shareholders from Continuing Operations	$	946	$	0.96	$	851	$	0.87
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $1)	—		—		3		—
Cost Program Management (net of taxes of $0)	—		—		1		—
COVID-19 Direct Costs (net of taxes of $3) (a)	—		—		5		0.01
Acquisition Related Costs (net of taxes of $3)(b)	—		—		7		0.01
ERP System Implementation Costs (net of taxes of $0 and $1, respectively)(c)	1		—		7		0.01
Separation Costs (net of taxes of $11 and $6, respectively)(d)	27		0.03		15		0.02
Income Tax-Related Adjustments (entire amount represents tax expense)(f)	92		0.09		(2)		—
Adjusted (non-GAAP) Operating Earnings	$	1,065	$	1.08	$	887	$	0.91

__________

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 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.

In connection with the separation, Exelon incurred separation costs impacting continuing operations of $14 million and $16 million on a pre-tax basis for the three months ended June 30, 2022 and 2021, respectively, and $38 million and $21 million on a pre-tax basis for the six months ended June 30, 2022 and 2021, respectively, which are recorded in Operating and maintenance expense. Total separation costs impacting continuing operations for the remainder of 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.

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Completed Distribution Base Rate Case Proceedings


Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement Increase		Approved Revenue Requirement Increase		Approved ROE		Approval Date	Rate Effective Date
ComEd - Illinois	April 16, 2021	Electric	$	51	$	46	7.36	%	December 1, 2021	January 1, 2022
PECO - Pennsylvania	March 30, 2021	Electric	246		132		N/A		November 18, 2021	January 1, 2022
BGE - Maryland	May 15, 2020 (amended September 11, 2020)	Electric	203		140		9.50	%	December 16, 2020	January 1, 2021
		Natural Gas	108		74		9.65	%
Pepco - District of Columbia	May 30, 2019 (amended June 1, 2020)	Electric	136		109		9.275	%	June 8, 2021	July 1, 2021
Pepco - Maryland	October 26, 2020 (amended March 31, 2021)	Electric	104		52		9.55	%	June 28, 2021	June 28, 2021
DPL - Maryland	September 1, 2021 (amended December 23, 2021)	Electric	27		13		9.60	%	March 2, 2022	March 2, 2022
ACE - New Jersey	December 9, 2020 (amended February 26, 2021)	Electric	67		41		9.60	%	July 14, 2021	January 1, 2022

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Pending Distribution Base Rate Case Proceedings

Registrant/Jurisdiction

Filing Date

Service

Requested Revenue Requirement Increase

Requested ROE

Expected Approval Timing

ComEd - Illinois

April 15, 2022

Electric

199

7.85

Fourth quarter of 2022

PECO - Pennsylvania

March 31, 2022

Natural Gas

10.95

Fourth quarter of 2022

DPL - Delaware

January 14, 2022 (amended February 28, 2022)

Natural Gas

10.30

First quarter of 2023

DPL - Maryland

May 19, 2022

Electric

10.25

Fourth quarter of 2022

Transmission Formula Rates

For 2022, the following total increases/(decreases) were included in the Utility Registrants' electric transmission formula rate updates. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information.


Registrant	Initial Revenue Requirement Increase		Annual Reconciliation (Decrease) Increase		Total Revenue Requirement Increase		Allowed Return on Rate Base		Allowed ROE
ComEd	$	24	$	(24)	$	—	8.11	%	11.50	%
PECO	23		16		39		7.30	%	10.35	%
BGE	25		(4)		16		7.30	%	10.50	%
Pepco	16		15		31		7.60	%	10.50	%
DPL	9		2		11		7.09	%	10.50	%
ACE	21		13		34		7.18	%	10.50	%

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 drivers and management strategies includes current developments of previously disclosed matters and new issues arising during the period that may impact future financial statements. This section should be read in conjunction with ITEM 1. Business in the 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 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 June 30, 2022, the Registrants’ critical accounting policies and estimates had not changed significantly from December 31, 2021. See ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS — Critical Accounting Policies and Estimates in the 2021 Recast Form 10-K for further information.

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Results of Operations by Registrant

Results of Operations — ComEd


	Three Months Ended June 30,				Favorable (Unfavorable) Variance		Six Months Ended June 30,				Favorable (Unfavorable) Variance
	2022		2021				2022		2021
Operating revenues	$	1,425	$	1,517	$	(92)	$	3,158	$	3,052	$	106
Operating expenses
Purchased power	283		500		217		921		1,025		104
Operating and maintenance	338		323		(15)		689		639		(50)
Depreciation and amortization	328		296		(32)		649		589		(60)
Taxes other than income taxes	90		77		(13)		185		153		(32)
Total operating expenses	1,039		1,196		157		2,444		2,406		(38)
Loss on sales of assets	(2)		—		(2)		(2)		—		(2)
Operating income	384		321		63		712		646		66
Other income and (deductions)
Interest expense, net	(104)		(98)		(6)		(204)		(193)		(11)
Other, net	13		15		(2)		26		22		4
Total other income and (deductions)	(91)		(83)		(8)		(178)		(171)		(7)
Income before income taxes	293		238		55		534		475		59
Income taxes	66		46		(20)		119		85		(34)
Net income	$	227	$	192	$	35	$	415	$	390	$	25

Three Months Ended June 30, 2022 Compared to Three Months Ended June 30, 2021. Net income increased by $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. See Note 12 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for additional information.

The changes in Operating revenues consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase (Decrease)		Increase (Decrease)
Distribution	$	65	$	110
Transmission	17		38
Energy efficiency	14		20
Other	—		3




	96		171
Regulatory required programs	(188)		(65)
Total increase	$	(92)	$	106

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 June 30, 2022 as compared to the same period in 2021, due to 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 June 30, 2022 as compared to the same period in 2021 primarily due to the impact of higher rate base and higher fully recoverable costs.

Energy Efficiency Revenue. FEJA provides for a performance-based formula rate, which requires an annual reconciliation of the revenue requirement in effect to the actual costs that the ICC determines are prudently and reasonably incurred in a given year. Under FEJA, energy efficiency revenue varies from year to year based upon fluctuations in the underlying costs, investments being recovered, and allowed ROE. Energy efficiency revenue increased for the three and six months ended June 30, 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 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 decrease of $217 million and $104 million for the three and six months ended 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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ComEd

The changes in Operating and maintenance expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	(Decrease) Increase		(Decrease) Increase

Storm-related costs	$	(1)	$	—
Pension and non-pension postretirement benefits expense	(7)		(14)
Labor, other benefits, contracting and materials	9		11

BSC costs	9		22

Other(a)	4		26
	14		45
Regulatory required programs(b)	1		5
Total increase	$	15	$	50

__________

(a)For the six months ended June 30, 2022, the increase is primarily due to the voluntary customer refund related to the ICC investigation of matters identified in the Deferred Prosecution Agreement. See Note 12 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for additional information related to the Deferred Prosecution Agreement.

(b)ComEd is allowed to recover from or refund to customers the difference between its annual credit loss expense and the amounts collected in rates annually through a rider mechanism.

The changes in Depreciation and amortization expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase		Increase
Depreciation and amortization(a)	$	19	$	33
Regulatory asset amortization(b)	13		27

Total increase	$	32	$	60

__________

(a)Reflects ongoing capital expenditures.

(b)Includes amortization of ComEd's energy efficiency formula rate regulatory asset.

Taxes other than income taxes increased by $13 million and by $32 million for the three and six months ended 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 22.5% and 19.3% for the three months ended 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 June 30,				Favorable (Unfavorable) Variance		Six Months Ended June 30,				Favorable (Unfavorable) Variance
	2022		2021				2022		2021
Operating revenues	$	816	$	693	$	123	$	1,863	$	1,582	$	281
Operating expenses
Purchased power and fuel	283		207		(76)		689		523		(166)
Operating and maintenance	215		209		(6)		463		443		(20)
Depreciation and amortization	93		87		(6)		185		173		(12)
Taxes other than income taxes	48		49		1		95		92		(3)
Total operating expenses	639		552		(87)		1,432		1,231		(201)

Operating income	177		141		36		431		351		80
Other income and (deductions)
Interest expense, net	(43)		(42)		(1)		(84)		(80)		(4)
Other, net	8		7		1		16		12		4
Total other income and (deductions)	(35)		(35)		—		(68)		(68)		—
Income before income taxes	142		106		36		363		283		80
Income taxes	9		2		(7)		24		12		(12)


Net income	$	133	$	104	$	29	$	339	$	271	$	68

Three Months Ended June 30, 2022 Compared to Three Months Ended June 30, 2021. Net income increased by $29 million, primarily due to increases in electric and gas distribution rates.

Six Months Ended June 30, 2022 Compared to Six Months Ended June 30, 2021. Net income increased by $68 million, primarily due to increases in electric and gas distribution rates.

The changes in Operating revenues consisted of the following:


	Three Months Ended June 30, 2022						Six Months Ended June 30, 2022
	(Decrease) Increase						(Decrease) Increase
	Electric		Gas		Total		Electric		Gas		Total
Weather	$	(1)	$	(1)	$	(2)	$	(5)	$	(5)	$	(10)
Volume	(2)		4		2		4		10		14
Pricing	32		6		38		65		23		88
Transmission	3		—		3		8		—		8
Other	6		1		7		11		4		15
	38		10		48		83		32		115
Regulatory required programs	58		17		75		95		71		166
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 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

PECO’s service territory for the three and six months ended June 30, 2022 compared to the same period in 2021 and normal weather consisted of the following:


	Three Months Ended June 30,			% Change
PECO Service Territory	2022	2021	Normal	2022 vs. 2021		2022 vs. Normal

Heating Degree-Days	385	404	424	(4.7)	%	(9.2)	%
Cooling Degree-Days	434	418	391	3.8	%	11.0	%
	Six Months Ended June 30,			% Change
	2022	2021	Normal	2022 vs. 2021		2022 vs. Normal
Heating Degree-Days	2,613	2,706	2,840	(3.4)	%	(8.0)	%
Cooling Degree-Days	435	423	392	2.8	%	11.0	%

Volume. Electric volume, exclusive of the effects of weather, for the three and six months ended June 30, 2022, compared to the same period in 2021, remained relatively consistent. Natural gas volume for the three and six months ended June 30, 2022 compared to the same period in 2021, increased due to retail load growth.


Electric Retail Deliveries to Customers (in GWhs)	Three Months Ended June 30,		% Change		Weather - Normal % Change(b)		Six Months Ended June 30,		% Change		Weather - Normal % Change(b)
	2022	2021					2022	2021
Residential	3,060	3,116	(1.8)	%	(1.1)	%	6,818	6,883	(0.9)	%	0.1	%
Small commercial & industrial	1,813	1,758	3.1	%	3.0	%	3,750	3,639	3.1	%	3.2	%
Large commercial & industrial	3,416	3,475	(1.7)	%	(1.8)	%	6,748	6,747	—	%	—	%
Public authorities & electric railroads	135	121	11.6	%	11.9	%	317	270	17.4	%	17.7	%
Total electric retail deliveries(a)	8,424	8,470	(0.5)	%	(0.4)	%	17,633	17,539	0.5	%	1.0	%


	As of June 30,
Number of Electric Customers	2022	2021
Residential	1,521,728	1,513,456
Small commercial & industrial	155,484	154,842
Large commercial & industrial	3,114	3,108
Public authorities & electric railroads	10,386	10,285
Total	1,690,712	1,681,691

__________

(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)	Three Months Ended June 30,		% Change		Weather - Normal % Change(b)		Six Months Ended June 30,		% Change		Weather - Normal % Change(b)
	2022	2021					2022	2021
Residential	5,206	5,027	3.6	%	4.9	%	26,043	25,701	1.3	%	4.4	%
Small commercial & industrial	3,638	3,121	16.6	%	17.2	%	14,184	13,291	6.7	%	8.4	%
Large commercial & industrial	4	2	100.0	%	12.6	%	14	9	55.6	%	11.4	%
Transportation	5,707	5,468	4.4	%	5.7	%	13,346	13,118	1.7	%	2.7	%
Total natural gas retail deliveries(a)	14,555	13,618	6.9	%	8.0	%	53,587	52,119	2.8	%	5.0	%

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PECO


	As of June 30,
Number of Natural Gas Customers	2022	2021
Residential	499,678	494,895
Small commercial & industrial	44,726	44,450
Large commercial & industrial	10	6
Transportation	659	677
Total	545,073	540,028

__________

(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.

Pricing for the three and six months ended June 30, 2022 compared to the same period in 2021 increased primarily due to increases 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 revenue for the three and six months ended June 30, 2022 compared to the same period in 2021 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 $76 million and $166 million for the three and six months ended 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.

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PECO

The changes in Operating and maintenance expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase (Decrease)		Increase (Decrease)
BSC costs	$	7	$	16
Credit loss expense	1		5
Storm-related costs	1		3
Pension and non-pension post retirement benefit expense	(3)		(4)
Labor, other benefits, contracting and materials	(6)		(8)
Other	4		3
	4		15
Regulatory required programs	2		5









Total increase	$	6	$	20

The changes in Depreciation and amortization expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase		Increase
Depreciation and amortization(a)	$	6	$	12
Regulatory asset amortization	—		—

Total increase	$	6	$	12

__________

(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.

Interest expense, net increased $1 million and $4 million for the three and six months ended June 30, 2022 compared to the same period in 2021, primarily due to the issuance of debt in 2021 and 2022.

Effective income tax rates were 6.3% and 1.9% for the three months ended 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 June 30,				Favorable (Unfavorable) Variance		Six Months Ended June 30,				Favorable (Unfavorable) Variance
	2022		2021				2022		2021
Operating revenues	$	786	$	682	$	104	$	1,940	$	1,656	$	284
Operating expenses
Purchased power and fuel	289		219		(70)		743		550		(193)
Operating and maintenance	205		193		(12)		423		390		(33)
Depreciation and amortization	152		141		(11)		322		293		(29)
Taxes other than income taxes	71		67		(4)		148		139		(9)
Total operating expenses	717		620		(97)		1,636		1,372		(264)

Operating income	69		62		7		304		284		20
Other income and (deductions)
Interest expense, net	(36)		(34)		(2)		(71)		(67)		(4)
Other, net	5		9		(4)		11		16		(5)
Total other income and (deductions)	(31)		(25)		(6)		(60)		(51)		(9)
Income before income taxes	38		37		1		244		233		11
Income taxes	1		(8)		(9)		10		(21)		(31)
Net income	$	37	$	45	$	(8)	$	234	$	254	$	(20)

Three Months Ended June 30, 2022 Compared to Three Months Ended 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 $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 June 30, 2022						Six Months Ended June 30, 2022
	Increase						Increase
	Electric		Gas		Total		Electric		Gas		Total
Distribution	$	17	$	5	$	22	$	31	$	15	$	46
Transmission	2		—		2		7		—		7
Other	3		2		5		10		5		15
	22		7		29		48		20		68
Regulatory required programs	50		25		75		128		88		216
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.

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BGE


	As of June 30,
Number of Electric Customers	2022	2021
Residential	1,200,397	1,192,135
Small commercial & industrial	115,769	114,682
Large commercial & industrial	12,721	12,528
Public authorities & electric railroads	267	267
Total	1,329,154	1,319,612


	As of June 30,
Number of Natural Gas Customers	2022	2021
Residential	653,409	647,534
Small commercial & industrial	38,227	38,223
Large commercial & industrial	6,211	6,132
Total	697,847	691,889

Distribution Revenue increased for the three and six months ended 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 June 30, 2022, compared to the same period in 2021, primarily due to increases in 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 June 30, 2022, compared to the same period in 2021, primarily due to an increase in late fees charged to customers.

Regulatory Required Programs represent revenues collected under approved riders to recover costs incurred for regulatory programs such as conservation, demand response, STRIDE, and the POLR mechanism. The riders are designed to provide full and current cost recovery, as well as a return in certain instances. The costs of these programs are included in Purchased power and fuel expense, Operating and maintenance expense, Depreciation and amortization expense, and Taxes other than income taxes. Customers have the choice to purchase electricity and natural gas from competitive electric generation and natural gas suppliers. Customer choice programs do not impact the volume of deliveries as BGE remains the distribution service provider for all customers and charges a regulated rate for distribution service, which is recorded in Operating revenues. For customers that choose to purchase electric generation or natural gas from competitive suppliers, BGE acts as the billing agent and therefore does not record Operating revenues or Purchased power and fuel expense related to the electricity and/or natural gas. For customers that choose to purchase electric generation or natural gas from BGE, BGE is permitted to recover the electricity and natural gas procurement costs from customers and therefore records the amounts related to the electricity and/or natural gas in Operating revenues and Purchased power and fuel expense. BGE recovers electricity and natural gas procurement costs from customers with a slight mark-up.

See Note 5 — Segment Information of the Combined Notes to Consolidated Financial Statements for the presentation of BGE's revenue disaggregation.

The increase of $70 million and $193 million for the three and six months ended 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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The changes in Operating and maintenance expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase (Decrease)		Increase (Decrease)
Labor, other benefits, contracting, and materials	$	5	$	7
Storm-related costs	(2)		(1)
Pension and non-pension postretirement benefits expense	(3)		(6)
BSC costs	6		14
Credit loss expense	—		14
Other	5		2
	11		30
Regulatory required programs	1		3

Total increase	$	12	$	33

The changes in Depreciation and amortization expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase		Increase
Depreciation and amortization(a)	$	9	$	19
Regulatory required programs	1		8
Regulatory asset amortization	1		2

Total increase	$	11	$	29

__________

(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 2.6% and (21.6)% for the three months ended 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 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 June 30,				(Unfavorable) Variance		Six Months Ended June 30,				(Unfavorable) Favorable Variance
	2022		2021				2022		2021
PHI	$	100	$	141	$	(41)	$	230	$	269	$	(39)
Pepco	70		75		(5)		116		134		(18)
DPL	21		30		(9)		77		86		(9)
ACE	11		37		(26)		37		51		(14)
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 June 30, 2022 Compared to Three Months Ended June 30, 2021. Net Income decreased by $41 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, an increase in storm costs at Pepco and DPL, credit loss expense at Pepco and DPL, higher contracting costs partially due to timing of maintenance projects at Pepco, depreciation and amortization expense, interest expense, and timing of excess deferred tax 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 June 30,				Favorable (Unfavorable) Variance		Six Months Ended June 30,				Favorable (Unfavorable) Variance
	2022		2021				2022		2021
Operating revenues	$	581	$	523	$	58	$	1,195	$	1,076	$	119


Operating expenses
Purchased power	162		133		(29)		375		298		(77)
Operating and maintenance	128		113		(15)		260		221		(39)
Depreciation and amortization	105		96		(9)		213		199		(14)
Taxes other than income taxes	92		87		(5)		186		177		(9)
Total operating expenses	487		429		(58)		1,034		895		(139)

Operating income	94		94		—		161		181		(20)
Other income and (deductions)
Interest expense, net	(38)		(35)		(3)		(74)		(69)		(5)
Other, net	13		13		—		26		25		1
Total other income and (deductions)	(25)		(22)		(3)		(48)		(44)		(4)
Income before income taxes	69		72		(3)		113		137		(24)
Income taxes	(1)		(3)		(2)		(3)		3		6
Net income	$	70	$	75	$	(5)	$	116	$	134	$	(18)

Three Months Ended June 30, 2022 Compared to Three Months Ended 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 by $18 million primarily due to an increase in depreciation expense, credit loss expense, storm costs, higher contracting costs partially due to timing of maintenance projects, and timing of excess deferred tax amortization, partially offset by the favorable impacts of the Maryland and District of Columbia multi-year plans.

The changes in Operating revenues consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase		Increase
Distribution	$	20	$	26
Transmission	5		8
Other	4		—
	29		34
Regulatory required programs	29		85
Total increase	$	58	$	119

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.

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Pepco


	As of June 30,
Number of Electric Customers	2022	2021
Residential	850,569	837,744
Small commercial & industrial	54,349	53,669
Large commercial & industrial	22,771	22,579
Public authorities & electric railroads	194	178
Total	927,883	914,170

Distribution Revenue increased for the three and six months ended June 30, 2022 compared to the same period in 2021 primarily due to favorable impacts of the Maryland and District of Columbia multi-year plans.

Transmission Revenue Under a FERC-approved formula, transmission revenue varies from year to year based upon fluctuations in the underlying costs and capital investments being recovered. Transmission revenue increased for the three and six months ended June 30, 2022, 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 $29 million and $77 million for the three and six months ended 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 June 30, 2022		Six Months Ended June 30, 2022
	Increase (Decrease)		Increase
BSC and PHISCO Costs	$	7	$	11
Labor, other benefits, contracting and materials(a)	6		9
Credit loss expense	5		9
Storm-related costs	—		6



Other	(5)		2
	13		37

Regulatory required programs	2		2
Total increase	$	15	$	39

__________

(a) Primarily reflects higher contracting costs partially due to timing of maintenance projects.

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The changes in Depreciation and amortization expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase		Increase (Decrease)
Depreciation and amortization(a)	$	6	$	11
Regulatory asset amortization	2		(3)
Regulatory required programs	1		6
Total increase	$	9	$	14

__________

(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.

Effective income tax rates were (1.4)% and (4.2)% for three months ended 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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DPL

Results of Operations — DPL


	Three Months Ended June 30,				Favorable (Unfavorable) Variance		Six Months Ended June 30,				Favorable (Unfavorable) Variance
	2022		2021				2022		2021
Operating revenues	$	332	$	298	$	34	$	763	$	680	$	83
Operating expenses
Purchased power and fuel	135		108		(27)		324		263		(61)
Operating and maintenance	88		80		(8)		181		164		(17)
Depreciation and amortization	56		51		(5)		113		104		(9)
Taxes other than income taxes	17		16		(1)		35		33		(2)
Total operating expenses	296		255		(41)		653		564		(89)

Operating income	36		43		(7)		110		116		(6)
Other income and (deductions)
Interest expense, net	(17)		(16)		(1)		(33)		(30)		(3)
Other, net	4		4		—		6		6		—
Total other income and (deductions)	(13)		(12)		(1)		(27)		(24)		(3)
Income before income taxes	23		31		(8)		83		92		(9)
Income taxes	2		1		(1)		6		6		—
Net income	$	21	$	30	$	(9)	$	77	$	86	$	(9)

Three Months Ended June 30, 2022 Compared to Three Months Ended 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 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 June 30, 2022						Six Months Ended June 30, 2022
	(Decrease) Increase						(Decrease) Increase
	Electric		Gas		Total		Electric		Gas		Total
Weather	$	(1)	$	—	$	(1)	$	(1)	$	—	$	(1)
Volume	(1)		2		1		3		3		6
Distribution	5		1		6		10		3		13
Transmission	(1)		—		(1)		2		—		2

	2		3		5		14		6		20
Regulatory required programs	18		11		29		43		20		63
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

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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 June 30, 2022 compared to same period in 2021 and normal weather consisted of the following:


	Three Months Ended June 30,			% Change
Delaware Electric Service Territory	2022	2021	Normal	2022 vs. 2021		2022 vs. Normal
Heating Degree-Days	441	480	471	(8.1)	%	(6.4)	%
Cooling Degree-Days	328	361	336	(9.1)	%	(2.4)	%

	Six Months Ended June 30,			% Change
	2022	2021	Normal	2022 vs. 2021		2022 vs. Normal
Heating Degree-Days	2,796	2,838	2,951	(1.5)	%	(5.3)	%
Cooling Degree-Days	331	364	336	(9.1)	%	(1.5)	%


	Three Months Ended June 30,			% Change
Delaware Natural Gas Service Territory	2022	2021	Normal	2022 vs. 2021		2022 vs. Normal
Heating Degree-Days	441	480	492	(8.1)	%	(10.4)	%

	Six Months Ended June 30,			% Change
	2022	2021	Normal	2022 vs. 2021		2022 vs. Normal
Heating Degree-Days	2,796	2,838	2,993	(1.5)	%	(6.6)	%

Volume, exclusive of the effects of weather, remained relatively consistent for the three months ended 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 in 2021 primarily due to customer growth and usage.


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)
	2022	2021					2022	2021
Residential	675	703	(4.0)	%	(1.7)	%	1,570	1,557	0.8	%	1.6	%
Small commercial & industrial	337	357	(5.6)	%	(4.8)	%	706	699	1.0	%	1.4	%
Large commercial & industrial	773	810	(4.6)	%	(4.2)	%	1,538	1,499	2.6	%	2.8	%
Public authorities & electric railroads	8	10	(20.0)	%	(19.9)	%	17	19	(10.5)	%	(7.9)	%
Total electric retail deliveries(a)	1,793	1,880	(4.6)	%	(3.5)	%	3,831	3,774	1.5	%	2.0	%


	As of June 30,
Number of Total Electric Customers (Maryland and Delaware)	2022	2021
Residential	479,728	475,061
Small commercial & industrial	63,574	62,880
Large commercial & industrial	1,222	1,213
Public authorities & electric railroads	598	607
Total	545,122	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.

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Natural Gas Retail Deliveries to Delaware Customers (in mmcf)	Three Months Ended June 30,		% Change		Weather - Normal % Change(b)		Six Months Ended June 30,		% Change		Weather - Normal % Change(b)
	2022	2021					2022	2021
Residential	983	713	37.9	%	44.6	%	5,436	5,107	6.4	%	6.3	%
Small commercial & industrial	570	430	32.6	%	39.2	%	2,550	2,295	11.1	%	12.0	%
Large commercial & industrial	402	393	2.3	%	2.3	%	863	853	1.2	%	1.1	%
Transportation	1,444	1,470	(1.8)	%	(0.7)	%	3,650	3,694	(1.2)	%	(0.7)	%
Total natural gas deliveries(a)	3,399	3,006	13.1	%	16.3	%	12,499	11,949	4.6	%	4.9	%


	As of June 30,
Number of Delaware Natural Gas Customers	2022	2021
Residential	128,715	127,503
Small commercial & industrial	10,068	9,953
Large commercial & industrial	16	18
Transportation	157	158
Total	138,956	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 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 remained relatively consistent for the three months ended 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 $27 million and $61 million for the three and six months ended 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.

The changes in Operating and maintenance expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase (Decrease)		Increase
BSC and PHISCO costs	$	4	$	7
Credit loss expense	2		4
Storm-related costs	—		3

Labor, other benefits, contracting and materials	2		1
Other	(1)		—
	7		15
Regulatory required programs	1		2
Total increase	$	8	$	17

The changes in Depreciation and amortization expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase		Increase (Decrease)
Depreciation and amortization(a)	$	5	$	9
Regulatory asset amortization	—		(1)
Regulatory required programs	—		1
Total increase	$	5	$	9

__________

(a)Depreciation and amortization increased primarily due to ongoing capital expenditures.

Effective income tax rates were 8.7% and 3.2% for the three months ended 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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ACE

Results of Operations — ACE


	Three Months Ended June 30,				(Unfavorable)Favorable Variance		Six Months Ended June 30,				Favorable (Unfavorable) Variance
	2022		2021				2022		2021
Operating revenues	$	309	$	319	$	(10)	$	658	$	629	$	29


Operating expenses
Purchased power	123		154		31		301		311		10
Operating and maintenance	86		73		(13)		170		150		(20)
Depreciation and amortization	72		40		(32)		118		87		(31)
Taxes other than income taxes	2		2		—		4		4		—
Total operating expenses	283		269		(14)		593		552		(41)

Operating income	26		50		(24)		65		77		(12)
Other income and (deductions)
Interest expense, net	(17)		(14)		(3)		(32)		(29)		(3)
Other, net	2		—		2		5		2		3
Total other income and (deductions)	(15)		(14)		(1)		(27)		(27)		—
Income before income taxes	11		36		(25)		38		50		(12)
Income taxes	—		(1)		(1)		1		(1)		(2)
Net income	$	11	$	37	$	(26)	$	37	$	51	$	(14)

Three Months Ended June 30, 2022 Compared to Three Months Ended 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 decreased by $14 million primarily due to the absence of favorable weather and volume as a result of the CIP, an increase in depreciation expense, various operating expenses, and timing of excess deferred tax amortization, partially offset by increases in distribution rates.

The changes in Operating revenues consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	(Decrease) Increase		(Decrease) Increase
Weather	$	(3)	$	(3)
Volume	(13)		(11)
Distribution	8		20
Transmission	(3)		3

	(11)		9




Regulatory required programs	1		20
Total (decrease) increase	$	(10)	$	29

Revenue Decoupling. The demand for electricity is affected by weather and customer usage. However, Operating revenues from electric distribution in New Jersey are not impacted by abnormal weather or usage per customer as a result of the CIP which became effective, prospectively, in the third quarter of 2021. The CIP compares current distribution revenues by customer class to approved target revenues established in ACE’s most recent distribution base rate case. The CIP is calculated annually, and recovery is subject to certain conditions, including an earnings test and ceilings on customer rate increases. While Operating revenues are not impacted by abnormal weather or usage per customer, they are impacted by changes in the number of customers. See Note 3 — Regulatory Matters of the Combined Notes to the Consolidated Financial Statements for additional information.

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ACE

Weather. Prior to the third quarter of 2021, the demand for electricity was affected by weather conditions. With respect to the electric business, very warm weather in summer months and very cold weather in winter months are referred to as “favorable weather conditions” because these weather conditions result in increased deliveries of electricity. Conversely, mild weather reduces demand. During the three and six months ended June 30, 2022 compared to the same period in 2021, Operating revenues related to weather decreased due to the absence of favorable impacts in the first and second quarter of 2022 as a result of the CIP.

Heating and cooling degree days are quantitative indices that reflect the demand for energy needed to heat or cool a home or business. Normal weather is determined based on historical average heating and cooling degree days for a 20-year period in ACE’s service territory. The changes in heating and cooling degree days in ACE’s service territory for the three and six months ended June 30, 2022 compared to same period in 2021 and normal weather consisted of the following:


	Three Months Ended June 30,		Normal	% Change
Heating and Cooling Degree-Days	2022	2021		2022 vs. 2021		2022 vs. Normal
Heating Degree-Days	533	525	540	1.5	%	(1.3)	%
Cooling Degree-Days	275	321	305	(14.3)	%	(9.8)	%


	Six Months Ended June 30,		Normal	% Change
Heating and Cooling Degree-Days	2022	2021		2022 vs. 2021		2022 vs. Normal
Heating Degree-Days	2,969	2,873	2,994	3.3	%	(0.8)	%
Cooling Degree-Days	277	325	305	(14.8)	%	(9.2)	%

Volume, exclusive of the effects of weather, decreased for the three and six months ended June 30, 2022 compared to the same period in 2021, due to the absence of favorable impacts in the first and second quarter of 2022 as a result of the CIP.


Electric Retail Deliveries to Customers (in GWhs)	Three Months Ended June 30,		% Change		Weather - Normal % Change(b)		Six Months Ended June 30,		% Change		Weather - Normal % Change(b)
	2022	2021					2022	2021
Residential	859	975	(11.9)	%	(9.7)	%	1,777	1,903	(6.6)	%	(6.0)	%
Small commercial & industrial	362	333	8.7	%	9.7	%	701	638	9.9	%	9.7	%
Large commercial & industrial	808	761	6.2	%	6.7	%	1,511	1,477	2.3	%	2.3	%
Public authorities & electric railroads	11	11	—	%	(5.8)	%	25	24	4.2	%	0.6	%
Total electric retail deliveries(a)	2,040	2,080	(1.9)	%	(0.5)	%	4,014	4,042	(0.7)	%	(0.5)	%


	As of June 30,
Number of Electric Customers	2022	2021
Residential	501,494	499,436
Small commercial & industrial	62,291	61,836
Large commercial & industrial	3,085	3,243
Public authorities & electric railroads	726	707
Total	567,596	565,222

__________

(a)Reflects delivery volumes from customers purchasing electricity directly from ACE and customers purchasing electricity from a competitive electric generation supplier as all customers are assessed distribution charges.

(b)Reflects the change in delivery volumes assuming normalized weather based on the historical 20-year average.

Distribution Revenue increased for the three and six months ended June 30, 2022 compared to the same period in 2021 due to higher distribution rates that became effective in January 2022.

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ACE

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 decreased for the three months ended June 30, 2022 compared to the same period in 2021, primarily due to decreases in underlying costs, partially offset by increases in capital investment. Transmission revenue increased for the six months ended June 30, 2022 compared to the same period in 2021, primarily due to an increase in capital investment.

Other Revenue includes rental revenue, service connection fees, 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 electricity, ZEC, and REC procurement costs without mark-up and therefore records equal and offsetting amounts in Operating revenues and Purchased power expense related to the electricity, ZECs, and RECs.

See Note 5 — Segment Information of the Combined Notes to Consolidated Financial Statements for the presentation of ACE's revenue disaggregation.

The decrease of $31 million and $10 million for the three and six months ended 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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ACE

The changes in Operating and maintenance expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase		Increase
Labor, other benefits, contracting and materials	$	4	$	4
BSC and PHISCO costs	3		4
Storm-related costs	1		2
Credit loss expense	1		—

Other	1		3
	10		13

Regulatory required programs(a)	3		7
Total increase	$	13	$	20

__________

(a)ACE is allowed to recover from or refund to customers the difference between its annual credit loss expense and the amounts collected in rates annually through the Societal Benefits Charge.

The changes in Depreciation and amortization expense consisted of the following:


	Three Months Ended June 30, 2022		Six Months Ended June 30, 2022
	Increase		Increase
Depreciation and amortization(a)	$	4	$	7
Regulatory asset amortization	—		1
Regulatory required programs(b)	28		23
Total increase	$	32	$	31

__________

(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 0.0% and (2.8)% for the three months ended 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 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 six months ended June 30, 2022 includes one month of cash flows from Generation. The Exelon Consolidated Statement of Cash Flows for the six months ended June 30, 2021 includes six months of cash flows from Generation. This is the primary reason for the changes in cash flows as shown in the tables unless otherwise noted below.

Cash Flows from Operating Activities

The Utility Registrants' cash flows from operating activities primarily result from the transmission and distribution of electricity and, in the case of PECO, BGE, and DPL, gas distribution services. The Utility Registrants' distribution services are provided to an established and diverse base of retail customers. The Utility Registrants' future cash flows may be affected by the economy, weather conditions, future legislative initiatives, future regulatory proceedings with respect to their rates or operations, and their ability to achieve operating cost reductions.

See Note 3 — Regulatory Matters of the 2021 Recast Form 10-K and Notes 3 — Regulatory Matters and 12 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for additional information on regulatory and legal proceedings and proposed legislation.

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The following table provides a summary of the change in cash flows from operating activities for the six months ended June 30, 2022 and 2021 by Registrant:


Increase (decrease) in cash flows from operating activities	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Net income (loss)	$	852	$	25	$	68	$	(20)	$	(39)	$	(18)	$	(9)	$	(14)
Adjustments to reconcile net income to cash:
Non-cash operating activities	(714)		(2)		14		82		164		57		33		72
Option premiums (paid), net	(41)		—		—		—		—		—		—		—
Collateral received, net	732		58		—		188		403		85		180		137
Income taxes	(167)		15		25		—		(1)		(4)		(8)		6
Pension and non-pension postretirement benefit contributions	(26)		(5)		2		12		(30)		—		(1)		(4)
Changes in regulatory assets and liabilities, net	(100)		(86)		(10)		25		(38)		2		2		(29)
Changes in working capital and other assets and liabilities	1,566		25		(61)		1		(46)		(16)		(7)		(17)
Increase 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 six months ended 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 assets and liabilities for the Utility Registrants and Exelon Corporate total $(74) million and for Generation total $1,640 million. The change for Generation primarily relates to the revolving accounts receivable financing arrangement. See Note 6 — Accounts Receivable of the 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 six months ended June 30, 2022 and 2021 by Registrant:


Increase (decrease) in cash flows from investing activities	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Capital expenditures	$	533	$	(46)	$	(81)	$	42	$	113	$	37	$	17	$	60

Investment in NDT fund sales, net	72		—		—		—		—		—		—		—
Collection of DPP	(2,040)		—		—		—		—		—		—		—
Proceeds from sales of assets and businesses	(708)		—		—		—		—		—		—		—
Changes in intercompany money pool	—		—		—		—		—		—		(64)		—

Other investing activities	(13)		3		1		(3)		5		4		1		—
(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 six months ended 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 2021 Form 10-K for additional information on the transaction and the DPP, including the $400 million of additional funding received in February and March of 2021.

•Proceeds from sales of assets and businesses decreased primarily due to the sale of a significant portion of Generation's solar business in 2021. See Note 2 — Mergers, Acquisitions, and Dispositions of the 2021 Form 10-K for additional information.

•Changes in intercompany money pool are driven by short-term borrowing needs. Refer below for more information regarding the intercompany money pool.

Cash Flows from Financing Activities

The following table provides a summary of the change in cash flows from financing activities for the six months ended June 30, 2022 and 2021 by Registrant:

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Increase (decrease) in cash flows from financing activities	Exelon		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Changes in short-term borrowings, net	$	369	$	290	$	210	$	(130)	$	(389)	$	(251)	$	(3)	$	(135)
Long-term debt, net	1,619		50		(375)		(100)		124		50		—		74
Changes in intercompany money pool	—		—		40		—		29		64		—		—

Dividends paid on common stock	84		(36)		(31)		(4)		—		(177)		7		191
Distributions to member	—		—		—		—		19		—		—		—
Contributions from(to) parent/member	—		(60)		(168)		186		144		249		24		(130)
Transfer of cash, restricted cash, and cash equivalents to Constellation	(2,594)		—		—		—		—		—		—		—
Other financing activities	(50)		(1)		(4)		(1)		(4)		(4)		(1)		—
(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 six months ended 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 17 — Commitments and Contingencies of the 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 six months ended June 30, 2022, other financing activities primarily consists of debt issuance costs. See Note 10 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information of the Registrants’ debt issuances.

Debt

See Note 10 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on the Registrants’ debt issuances.

During the six months ended June 30, 2022, the following long-term debt was retired and/or redeemed:

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Company(a)	Type	Interest Rate		Maturity	Amount
Exelon	Junior Subordinated Notes	3.50	%	May 2, 2022	$	1,150
Exelon	Long-Term Software License Agreement	3.96	%	May 1, 2024	2
PECO	First Mortgage Bonds	2.375	%	September 15, 2022	350
Pepco	First Mortgage Bonds	3.05	%	April 1, 2022	200

__________

(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 six months ended June 30, 2022 and for the third quarter of 2022 were as follows:

Period

Declaration Date

Shareholder of Record Date

Dividend Payable Date

Cash per Share(a)

First Quarter 2022

February 8, 2022

February 25, 2022

March 10, 2022

0.3375

Second Quarter 2022

April 26, 2022

May 13, 2022

June 10, 2022

0.3375

Third Quarter 2022

July 26, 2022

August 15, 2022

September 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 $3.6 billion was available to support additional commercial paper as of June 30, 2022, and of which no financial institution has more than 6% of the aggregate commitments for the Registrants. The Registrants had access to the commercial paper markets and had availability under their revolving credit facilities during the six months ended 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 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 June 30, 2022 and available credit facility capacity prior to any incremental collateral at June 30, 2022:

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	PJM Credit Policy Collateral		Other Incremental Collateral Required(a)		Available Credit Facility Capacity Prior to Any Incremental Collateral
ComEd	$	12	$	—	$	995
PECO	2		37		390
BGE	3		75		600

Pepco	3		—		257
DPL	2		15		300
ACE	1		—		300

__________

(a)Represents incremental collateral related to natural gas procurement contracts.

Capital Expenditure Spending

As of June 30, 2022, the most recent estimates of capital expenditures for plant additions and improvements for 2022 are as follows:


(In millions)	Transmission	Distribution	Gas	Total
Exelon	N/A	N/A	N/A	$	6,900
ComEd	475	2,000	N/A	2,475
PECO	200	825	325	1,350
BGE	250	500	475	1,225
PHI	625	1,150	75	1,850
Pepco	275	625	N/A	900
DPL	150	250	75	475
ACE	200	275	N/A	475

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).

Credit Facilities

Exelon Corporate, ComEd, and BGE meet their short-term liquidity requirements primarily through the issuance of commercial paper. PECO meets its short-term liquidity requirements primarily through the issuance of

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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 six months ended June 30, 2022. On January 14, 2022, Fitch lowered Exelon Corporate's long-term and senior unsecured ratings from BBB+ to BBB and affirmed the short-term rating of F2. In addition, Fitch upgraded Pepco, ACE, and PHI's long-term rating from BBB to BBB+ and upgraded Pepco and ACE's senior secured rating from A- to A.

Intercompany Money Pool

To provide an additional short-term borrowing option that will generally be more favorable to the borrowing participants than the cost of external financing, both Exelon and PHI operate an intercompany money pool. Maximum amounts contributed to and borrowed from the money pool by participant and the net contribution or borrowing as of June 30, 2022, are presented in the following table. ACE had no activity within the PHI intercompany money pool during the six months ended June 30, 2022.

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	During the Six Months Ended June 30, 2022				As of June 30, 2022
Exelon Intercompany Money Pool	Maximum Contributed		Maximum Borrowed		Contributed (Borrowed)
Exelon Corporate	$	396	$	—	$	287
PECO	60		(105)		—
BSC	—		(377)		(308)
PHI Corporate	—		(54)		(24)
PCI	50		—		45


	During the Six Months Ended June 30, 2022				As of June 30, 2022
PHI Intercompany Money Pool	Maximum Contributed		Maximum Borrowed		Contributed (Borrowed)
Pepco	$	—	$	(85)	$	(73)
DPL	85		—		73

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 shelf registration statement or to access the private placement markets will depend on a number of factors at the time of the proposed sale, including other required regulatory approvals, as applicable, the current financial condition of the Registrant, its securities ratings and market conditions.

Regulatory Authorizations

The Utility Registrants are required to obtain short-term and long-term financing authority from Federal and State Commissions as follows:

As of June 30, 2022

Short-term Financing Authority

Remaining Long-term Financing Authority

Commission

Expiration Date

Amount

Commission

Expiration Date

Amount

ComEd(a)

FERC

December 31, 2023

2,500

ICC

January 1, 2025

1,343

PECO(b)

FERC

December 31, 2023

1,500

PAPUC

December 31, 2024

1,550

BGE

FERC

December 31, 2023

700

MDPSC

N/A

—

Pepco(c)

FERC

December 31, 2023

500

MDPSC / DCPSC

2022 & 2025

1,625

DPL

FERC

December 31, 2023

500

MDPSC / DEPSC

December 31, 2022

ACE(d)

NJBPU

December 31, 2023

350

NJBPU

December 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)As of June 30, 2022, Pepco had $225 million in long-term financing authority from 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 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 13 — Retirement Benefits of the 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 Within												Total Fair Value
	2022		2023		2024		2025		2026		2027 and Beyond		Total Fair Value
Prices based on model or other valuation methods (Level 3)	$	11	$	(2)	$	(14)	$	(16)	$	(15)	$	(52)	$	(88)

ITEM 4. CONTROLS AND PROCEDURES

During the second 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 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 second 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 the 2021 Form 10-K, (b) Notes 3 — Regulatory Matters and 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 June 30, 2022, the Registrants' risk factors were consistent with the risk factors described in the 2021 Form 10-K in ITEM 1A. RISK FACTORS, except for the updates below.

The Registrants are subject to physical security and cybersecurity risks (All Registrants).

The Registrants face physical security and cybersecurity risks. Threat sources, including sophisticated nation-state actors, continue to seek to exploit potential vulnerabilities in the electric and natural gas utility industry, grid infrastructure, and other energy infrastructures, and these attacks and disruptions, both physical and cyber, are becoming increasingly sophisticated and dynamic. Continued implementation of advanced digital technologies

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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 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

3.1*			Exelon Corporation Amended and Restated Bylaws dated as of August 3, 2022

4.1			One Hundred and Twenty-First Supplemental Indenture dated as of May 1, 2022, among PECO Energy Company and U.S. Bank , N.A., as trustee (File 001-16844, Form 8-K dated May 24, 2022, Exhibit 4.1)

4.2			Form of 4.550% Note due 2052 issued June 6, 2022 by Baltimore Gas and Electric Company (File 001-01910, Form 8-K dated June 6, 2022, Exhibit 4.2)

14*			Exelon Code of Business Conduct, as amended June 20, 2022











101.INS			Inline XBRL Instance Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

101.SCH			Inline XBRL Taxonomy Extension Schema Document.

101.CAL			Inline XBRL Taxonomy Extension Calculation Linkbase Document.

101.DEF			Inline XBRL Taxonomy Extension Definition Linkbase Document.

101.LAB			Inline XBRL Taxonomy Extension Labels Linkbase Document.

101.PRE			Inline XBRL Taxonomy Extension Presentation Linkbase Document.

104			Cover 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 June 30, 2022 filed by the following officers for the following companies:


Exhibit No.			Description
31-1			Filed by Christopher M. Crane for Exelon Corporation

31-2			Filed by Joseph Nigro for Exelon Corporation

31-3			Filed by Gil C. Quiniones for Commonwealth Edison Company

31-4			Filed by Elisabeth J. Graham for Commonwealth Edison Company

31-5			Filed by Michael A. Innocenzo for PECO Energy Company

31-6			Filed by Robert J. Stefani for PECO Energy Company

31-7			Filed by Carim V. Khouzami for Baltimore Gas and Electric Company

31-8			Filed by David M. Vahos for Baltimore Gas and Electric Company

31-9			Filed by J. Tyler Anthony for Pepco Holdings LLC

31-10			Filed by Phillip S. Barnett for Pepco Holdings LLC

31-11			Filed by J. Tyler Anthony for Potomac Electric Power Company

31-12			Filed by Phillip S. Barnett for Potomac Electric Power Company

31-13			Filed by J. Tyler Anthony for Delmarva Power & Light Company

31-14			Filed by Phillip S. Barnett for Delmarva Power & Light Company

31-15			Filed by J. Tyler Anthony for Atlantic City Electric Company

31-16			Filed by Phillip S. Barnett for Atlantic City Electric Company

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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 June 30, 2022 filed by the following officers for the following companies:


Exhibit No.			Description
32-1			Filed by Christopher M. Crane for Exelon Corporation

32-2			Filed by Joseph Nigro for Exelon Corporation

32-3			Filed by Gil C. Quiniones for Commonwealth Edison Company

32-4			Filed by Elisabeth J. Graham for Commonwealth Edison Company

32-5			Filed by Michael A. Innocenzo for PECO Energy Company

32-6			Filed by Robert J. Stefani for PECO Energy Company

32-7			Filed by Carim V. Khouzami for Baltimore Gas and Electric Company

32-8			Filed by David M. Vahos for Baltimore Gas and Electric Company

32-9			Filed by J. Tyler Anthony for Pepco Holdings LLC

32-10			Filed by Phillip S. Barnett for Pepco Holdings LLC

32-11			Filed by J. Tyler Anthony for Potomac Electric Power Company

32-12			Filed by Phillip S. Barnett for Potomac Electric Power Company

32-13			Filed by J. Tyler Anthony for Delmarva Power & Light Company

32-14			Filed by Phillip S. Barnett for Delmarva Power & Light Company

32-15			Filed by J. Tyler Anthony for Atlantic City Electric Company

32-16			Filed by Phillip S. Barnett for Atlantic City Electric Company

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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. Crane						Joseph Nigro
President, Chief Executive Officer (Principal Executive Officer) and Director						Senior Executive Vice President and Chief Financial Officer (Principal Financial Officer)

/s/ JOSEPH R. TRPIK
Joseph R. Trpik
Senior Vice President and Corporate Controller (Principal Accounting Officer)

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. Quiniones						Elisabeth 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)

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. Innocenzo						Robert 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)

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. Khouzami						David 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)

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 Anthony						Phillip 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)

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 Anthony						Phillip 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)

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 Anthony						Phillip 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)

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 Anthony						Phillip 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)

August 3, 2022

159

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