10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the Quarterly Period Ended March 31, 2021

or

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

Commission File Number	Name of Registrant; State or Other Jurisdiction of Incorporation; Address of Principal Executive Offices; and Telephone Number	IRS Employer Identification Number
001-16169	EXELON CORPORATION	23-2990190
	(a Pennsylvania corporation) 10 South Dearborn Street P.O. Box 805379 Chicago, Illinois 60680-5379 (800) 483-3220
333-85496	EXELON GENERATION COMPANY, LLC	23-3064219
	(a Pennsylvania limited liability company) 300 Exelon Way Kennett Square, Pennsylvania 19348-2473 (610) 765-5959
001-01839	COMMONWEALTH EDISON COMPANY	36-0938600
	(an Illinois corporation) 440 South LaSalle Street Chicago, Illinois 60605-1028 (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 (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 (202) 872-2000
001-01405	DELMARVA POWER & LIGHT COMPANY	51-0084283
	(a Delaware and Virginia corporation) 500 North Wakefield Drive Newark, Delaware 19702 (202) 872-2000
001-03559	ATLANTIC CITY ELECTRIC COMPANY	21-0398280
	(a New Jersey corporation) 500 North Wakefield Drive Newark, Delaware 19702 (202) 872-2000

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

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
EXELON CORPORATION:
Common Stock, without par value	EXC	The Nasdaq Stock Market LLC
PECO ENERGY COMPANY:
Trust Receipts of PECO Energy Capital Trust III, each representing a 7.38% Cumulative Preferred Security, Series D, $25 stated value, issued by PECO Energy Capital, L.P. and unconditionally guaranteed by PECO Energy Company	EXC/28	New York Stock Exchange

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

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

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

Exelon Corporation	Large Accelerated Filer	x	Accelerated Filer	☐	Non-accelerated Filer	☐	Smaller Reporting Company	☐	Emerging Growth Company	☐
Exelon Generation Company, LLC	Large Accelerated Filer	☐	Accelerated Filer	☐	Non-accelerated Filer	x	Smaller Reporting Company	☐	Emerging Growth Company	☐
Commonwealth Edison Company	Large Accelerated Filer	☐	Accelerated Filer	☐	Non-accelerated Filer	x	Smaller Reporting Company	☐	Emerging Growth Company	☐
PECO Energy Company	Large Accelerated Filer	☐	Accelerated Filer	☐	Non-accelerated Filer	x	Smaller Reporting Company	☐	Emerging Growth Company	☐
Baltimore Gas and Electric Company	Large Accelerated Filer	☐	Accelerated Filer	☐	Non-accelerated Filer	x	Smaller Reporting Company	☐	Emerging Growth Company	☐
Pepco Holdings LLC	Large Accelerated Filer	☐	Accelerated Filer	☐	Non-accelerated Filer	x	Smaller Reporting Company	☐	Emerging Growth Company	☐
Potomac Electric Power Company	Large Accelerated Filer	☐	Accelerated Filer	☐	Non-accelerated Filer	x	Smaller Reporting Company	☐	Emerging Growth Company	☐
Delmarva Power & Light Company	Large Accelerated Filer	☐	Accelerated Filer	☐	Non-accelerated Filer	x	Smaller Reporting Company	☐	Emerging Growth Company	☐
Atlantic City Electric Company	Large Accelerated Filer	☐	Accelerated Filer	☐	Non-accelerated Filer	x	Smaller Reporting Company	☐	Emerging Growth Company	☐

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

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

The number of shares outstanding of each registrant’s common stock as of March 31, 2021 was:

Exelon Corporation Common Stock, without par value	977,175,235
Exelon Generation Company, LLC	not applicable
Commonwealth Edison Company Common Stock, $12.50 par value	127,021,380
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		8
CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING INFORMATION		8
WHERE TO FIND MORE INFORMATION		8
PART I.	FINANCIAL INFORMATION	9
ITEM 1.	FINANCIAL STATEMENTS	9
	Exelon Corporation
	Consolidated Statements of Operations and Comprehensive Income	10
	Consolidated Statements of Cash Flows	11
	Consolidated Balance Sheets	12
	Consolidated Statements of Changes in Shareholders’ Equity	14
	Exelon Generation Company, LLC
	Consolidated Statements of Operations and Comprehensive Income	15
	Consolidated Statements of Cash Flows	16
	Consolidated Balance Sheets	17
	Consolidated Statements of Changes in Equity	19
	Commonwealth Edison Company
	Consolidated Statements of Operations and Comprehensive Income	20
	Consolidated Statements of Cash Flows	21
	Consolidated Balance Sheets	22
	Consolidated Statements of Changes in Shareholders' Equity	24
	PECO Energy Company
	Consolidated Statements of Operations and Comprehensive Income	25
	Consolidated Statements of Cash Flows	26
	Consolidated Balance Sheets	27
	Consolidated Statements of Changes in Shareholder's Equity	29
	Baltimore Gas and Electric Company
	Statements of Operations and Comprehensive Income	30
	Statements of Cash Flows	31
	Balance Sheets	32
	Statements of Changes in Shareholder's Equity	34
	Pepco Holdings LLC
	Consolidated Statements of Operations and Comprehensive Income	35
	Consolidated Statements of Cash Flows	36
	Consolidated Balance Sheets	37
	Consolidated Statements of Changes in Equity	39

1

	Page No.
Potomac Electric Power Company
Statements of Operations and Comprehensive Income	40
Statements of Cash Flows	41
Balance Sheets	42
Statements of Changes in Shareholder's Equity	44
Delmarva Power & Light Company
Statements of Operations and Comprehensive Income	45
Statements of Cash Flows	46
Balance Sheets	47
Statements of Changes in Shareholder’s Equity	49
Atlantic City Electric Company
Consolidated Statements of Operations and Comprehensive Income	50
Consolidated Statements of Cash Flows	51
Consolidated Balance Sheets	52
Consolidated Statements of Changes in Shareholder’s Equity	54
Combined Notes to Consolidated Financial Statements
1. Significant Accounting Policies	55
2. Mergers, Acquisitions and Dispositions	56
3. Regulatory Matters	57
4. Revenue from Contracts with Customers	62
5. Segment Information	64
6. Accounts Receivable	72
7. Early Plant Retirements	75
8. Nuclear Decommissioning	77
9. Income Taxes	79
10. Retirement Benefits	80
11. Derivative Financial Instruments	82
12. Debt and Credit Agreements	87
13. Fair Value of Financial Assets and Liabilities	90
14. Commitments and Contingencies	100
15. Changes in Accumulated Other Comprehensive Income	107
16. Variable Interest Entities	108
17. Supplemental Financial Information	112
18. Related Party Transactions	117
19. Planned Separation	120

2

		Page No.
ITEM 2.	MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	121
	Exelon Corporation	121
	Executive Overview	121
	Financial Results of Operations	121
	Significant 2021 Transactions and Developments	124
	Other Key Business Drivers and Management Strategies	126
	Critical Accounting Policies and Estimates	127
	Results of Operations By Registrant	127
	Exelon Generation Company, LLC	128
	Commonwealth Edison Company	134
	PECO Energy Company	137
	Baltimore Gas and Electric Company	141
	Pepco Holdings LLC	144
	Potomac Electric Power Company	145
	Delmarva Power & Light Company	147
	Atlantic City Electric Company	151
	Liquidity and Capital Resources	154
	Contractual Obligations and Off-Balance Sheet Arrangements	161
ITEM 3.	QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	162
ITEM 4.	CONTROLS AND PROCEDURES	166
PART II.	OTHER INFORMATION	167
ITEM 1.	LEGAL PROCEEDINGS	167
ITEM 1A.	RISK FACTORS	167
ITEM 4.	MINE SAFETY DISCLOSURES	167
ITEM 5.	OTHER INFORMATION	167
ITEM 6.	EXHIBITS	168
SIGNATURES		171
	Exelon Corporation	171
	Exelon Generation Company, LLC	172
	Commonwealth Edison Company	173
	PECO Energy Company	174
	Baltimore Gas and Electric Company	175
	Pepco Holdings LLC	176
	Potomac Electric Power Company	177
	Delmarva Power & Light Company	178
	Atlantic City Electric Company	179

3

GLOSSARY OF TERMS AND ABBREVIATIONS
Exelon Corporation and Related Entities
Exelon	Exelon Corporation
Generation	Exelon Generation Company, LLC
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, Generation, 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
Antelope Valley	Antelope Valley Solar Ranch One
BSC	Exelon Business Services Company, LLC
CENG	Constellation Energy Nuclear Group, LLC
Constellation	Constellation Energy Group, Inc.
EGR IV	ExGen Renewables IV, LLC
EGRP	ExGen Renewables Partners, LLC
Exelon Corporate	Exelon in its corporate capacity as a holding company
FitzPatrick	James A. FitzPatrick nuclear generating station
NER	NewEnergy Receivables LLC
PCI	Potomac Capital Investment Corporation and its subsidiaries
PECO Trust III	PECO Energy Capital Trust III
PECO Trust IV	PECO Energy Capital Trust IV
Pepco Energy Services	Pepco Energy Services, Inc. and its subsidiaries
PHI Corporate	PHI in its corporate capacity as a holding company
PHISCO	PHI Service Company
RPG	Renewable Power Generation
SolGen	SolGen, LLC
TMI	Three Mile Island nuclear facility

4

GLOSSARY OF TERMS AND ABBREVIATIONS
Other Terms and Abbreviations
Note - of the 2020 Form 10-K	Reference to specific Combined Note to Consolidated Financial Statements within Exelon's 2020 Annual Report on Form 10-K
AEC	Alternative Energy Credit that is issued for each megawatt hour of generation from a qualified alternative energy source
AESO	Alberta Electric Systems Operator
AFUDC	Allowance for Funds Used During Construction
AMI	Advanced Metering Infrastructure
AOCI	Accumulated Other Comprehensive Income (Loss)
ARC	Asset Retirement Cost
ARO	Asset Retirement Obligation
BGS	Basic Generation Service
CBA	Collective Bargaining Agreement
CERCLA	Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended
CES	Clean Energy Standard
Clean Water Act	Federal Water Pollution Control Amendments of 1972, as amended
CODM	Chief operating decision maker(s)
D.C. Circuit Court	United States Court of Appeals for the District of Columbia Circuit
DC PLUG	District of Columbia Power Line Undergrounding Initiative
DCPSC	Public Service Commission of the District of Columbia
DOE	United States Department of Energy
DOEE	District of Columbia Department of Energy & Environment
DOJ	United States Department of Justice
DPP	Deferred Purchase Price
DPSC	Delaware Public Service Commission
EDF	Electricite de France SA and its subsidiaries
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
FASB	Financial Accounting Standards Board
FEJA	Illinois Public Act 99-0906 or Future Energy Jobs Act
FERC	Federal Energy Regulatory Commission
FRCC	Florida Reliability Coordinating Council
FRR	Fixed Resource Requirement
GAAP	Generally Accepted Accounting Principles in the United States
GCR	Gas Cost Rate
GSA	Generation Supply Adjustment
IBEW	International Brotherhood of Electrical Workers
ICC	Illinois Commerce Commission
ICE	Intercontinental Exchange
IPA	Illinois Power Agency
IRC	Internal Revenue Code
IRS	Internal Revenue Service
ISO	Independent System Operator
ISO-NE	Independent System Operator New England Inc.

5

GLOSSARY OF TERMS AND ABBREVIATIONS
Other Terms and Abbreviations
LIBOR	London Interbank Offered Rate
MDE	Maryland Department of the Environment
MDPSC	Maryland Public Service Commission
MGP	Manufactured Gas Plant
MISO	Midcontinent Independent System Operator, Inc.
mmcf	Million Cubic Feet
MOPR	Minimum Offer Price Rule
MPSC	Missouri Public Service Commission
MW	Megawatt
MWh	Megawatt hour
NAV	Net Asset Value
N/A	Not applicable
NDT	Nuclear Decommissioning Trust
NERC	North American Electric Reliability Corporation
NGX	Natural Gas Exchange
NJBPU	New Jersey Board of Public Utilities
Non-Regulatory Agreement Units	Nuclear generating units or portions thereof whose decommissioning-related activities are not subject to contractual elimination under regulatory accounting
NOSA	Nuclear Operating Services Agreement
NPNS	Normal Purchase Normal Sale scope exception
NRC	Nuclear Regulatory Commission
NYISO	New York Independent System Operator Inc.
NYMEX	New York Mercantile Exchange
NYPSC	New York Public Service Commission
OCI	Other Comprehensive Income
OIESO	Ontario Independent Electricity System Operator
OPEB	Other Postretirement Employee Benefits
PAPUC	Pennsylvania Public Utility Commission
PGC	Purchased Gas Cost Clause
PG&E	Pacific Gas and Electric Company
PJM	PJM Interconnection, LLC
POLR	Provider of Last Resort
PPA	Power Purchase Agreement
PPE	Property, plant, and equipment
Price-Anderson Act	Price-Anderson Nuclear Industries Indemnity Act of 1957
PRP	Potentially Responsible Parties
PSDAR	Post-Shutdown Decommissioning Activities Report
PSEG	Public Service Enterprise Group Incorporated
PUCT	Public Utility Commission of Texas
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
RMC	Risk Management Committee

6

GLOSSARY OF TERMS AND ABBREVIATIONS
Other Terms and Abbreviations
RNF	Revenues Net of Purchased Power and Fuel Expense
ROE	Return on equity
ROU	Right-of-use
RTO	Regional Transmission Organization
S&P	Standard & Poor’s Ratings Services
SEC	United States Securities and Exchange Commission
SERC	SERC Reliability Corporation (formerly Southeast Electric Reliability Council)
SNF	Spent Nuclear Fuel
SOS	Standard Offer Service
STRIDE	Maryland Strategic Infrastructure Development and Enhancement Program
Transition Bonds	Transition Bonds issued by ACE Funding
VIE	Variable Interest Entity
WECC	Western Electric Coordinating Council
ZEC	Zero Emission Credit, or Zero Emission Certificate
ZES	Zero Emission Standard

7

FILING FORMAT

This combined Form 10-Q is being filed separately by Exelon Corporation, Exelon Generation Company, LLC, 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 including, among others, those related to the timing, manner, tax-free nature, and expected benefits associated with the potential separation of Exelon’s competitive power generation and customer-facing energy business from its six regulated electric and gas utilities. Words such as “could,” “may,” “expects,” “anticipates,” “will,” “targets,” “goals,” “projects,” “intends,” “plans,” “believes,” “seeks,” “estimates,” “predicts,” and variations on such words, and similar expressions that reflect our current views with respect to future events and operational, economic, and financial performance, are intended to identify such forward-looking statements.

The factors that could cause actual results to differ materially from the forward-looking statements made by the Registrants include those factors discussed herein, as well as the items discussed in (1) the Registrants' combined 2020 Annual Report on Form 10-K in (a) Part I, ITEM 1A. Risk Factors, (b) Part II, ITEM 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) Part II, ITEM 8. Financial Statements and Supplementary Data: Note 19, Commitments and Contingencies; (2) this Quarterly Report on Form 10-Q in (a) Part II, ITEM 1A. Risk Factors, (b) Part I, ITEM 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations, and (c) Part I, ITEM 1. Financial Statements: Note 14, Commitments and Contingencies; and (3) other factors discussed in filings with the SEC by the Registrants.

Investors are cautioned not to place undue reliance on these forward-looking statements, which apply only as of the date of this Report. None of the Registrants undertakes any obligation to publicly release any revision to its forward-looking statements to reflect events or circumstances after the date of this Report.

WHERE TO FIND MORE INFORMATION

The SEC maintains an Internet site at www.sec.gov that contains reports, proxy and information statements, and other information that the Registrants file electronically with the SEC. These documents are also available to the public from commercial document retrieval services and the Registrants' website at www.exeloncorp.com. Information contained on the Registrants' website shall not be deemed incorporated into, or to be a part of, this Report.

8

PART I. FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

9

EXELON CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions, except per share data)	2021		2020
Operating revenues
Competitive businesses revenues	$	5,265	$	4,404
Rate-regulated utility revenues	4,496		4,276
Revenues from alternative revenue programs	129		67
Total operating revenues	9,890		8,747
Operating expenses
Competitive businesses purchased power and fuel	4,610		2,710
Rate-regulated utility purchased power and fuel	1,358		1,157
Operating and maintenance	1,979		2,204
Depreciation and amortization	1,697		1,021
Taxes other than income taxes	438		437
Total operating expenses	10,082		7,529
Gain on sales of assets and businesses	71		2
Operating (loss) income	(121)		1,220
Other income and (deductions)
Interest expense, net	(380)		(404)
Interest expense to affiliates	(6)		(6)
Other, net	225		(725)
Total other income and (deductions)	(161)		(1,135)
(Loss) income before income taxes	(282)		85
Income taxes	(19)		(294)
Equity in losses of unconsolidated affiliates	(1)		(3)
Net (loss) income	(264)		376
Net income (loss) attributable to noncontrolling interests	25		(206)
Net (loss) income attributable to common shareholders	$	(289)	$	582
Comprehensive income, net of income taxes
Net (loss) income	$	(264)	$	376
Other comprehensive income (loss), net of income taxes
Pension and non-pension postretirement benefit plans:
Prior service benefit reclassified to periodic benefit cost	(1)		(10)
Actuarial loss reclassified to periodic benefit cost	56		47
Pension and non-pension postretirement benefit plan valuation adjustment	(2)		(7)
Unrealized loss on cash flow hedges	—		(1)
Unrealized gain (loss) on foreign currency translation	1		(8)
Other comprehensive income	54		21
Comprehensive (loss) income	(210)		397
Comprehensive income (loss) attributable to noncontrolling interests	25		(206)
Comprehensive (loss) income attributable to common shareholders	$	(235)	$	603
Average shares of common stock outstanding:
Basic	977		975
Assumed exercise and/or distributions of stock-based awards	—		1
Diluted(a)	977		976
(Losses) earnings per average common share
Basic	$	(0.30)	$	0.60
Diluted	$	(0.30)	$	0.60

__________

(a)The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was less than 1 million for the three months ended March 31, 2021 and March 31, 2020.

See the Combined Notes to Consolidated Financial Statements

10

EXELON CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Cash flows from operating activities
Net (loss) income	$	(264)	$	376
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	2,104		1,378
Asset impairments	1		8
Gain on sales of assets and businesses	(71)		—
Deferred income taxes and amortization of investment tax credits	(142)		(245)
Net fair value changes related to derivatives	(178)		(132)
Net realized and unrealized (gains) losses on NDT funds	(118)		651
Unrealized loss on equity investments	23		—
Other non-cash operating activities	(170)		273
Changes in assets and liabilities:
Accounts receivable	(372)		800
Inventories	77		81
Accounts payable and accrued expenses	(176)		(976)
Option premiums received (paid), net	16		(38)
Collateral received (posted), net	273		(21)
Income taxes	113		(56)
Pension and non-pension postretirement benefit contributions	(537)		(531)
Other assets and liabilities	(1,840)		(488)
Net cash flows (used in) provided by operating activities	(1,261)		1,080
Cash flows from investing activities
Capital expenditures	(2,140)		(2,016)
Proceeds from NDT fund sales	2,908		1,183
Investment in NDT funds	(2,939)		(1,234)
Collection of DPP	1,574		—
Proceeds from sales of assets and businesses	680		—
Other investing activities	12		(8)
Net cash flows provided by (used in) investing activities	95		(2,075)
Cash flows from financing activities
Changes in short-term borrowings	597		109
Proceeds from short-term borrowings with maturities greater than 90 days	500		500
Issuance of long-term debt	1,705		2,652
Retirement of long-term debt	(79)		(1,032)
Dividends paid on common stock	(374)		(373)
Proceeds from employee stock plans	31		30
Other financing activities	(46)		(21)
Net cash flows provided by financing activities	2,334		1,865
Increase in cash, restricted cash, and cash equivalents	1,168		870
Cash, restricted cash, and cash equivalents at beginning of period	1,166		1,122
Cash, restricted cash, and cash equivalents at end of period	$	2,334	$	1,992
Supplemental cash flow information
Decrease in capital expenditures not paid	$	(324)	$	(180)
Increase in DPP	1,339		—

See the Combined Notes to Consolidated Financial Statements

11

EXELON CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
ASSETS
Current assets
Cash and cash equivalents	$	1,908	$	663
Restricted cash and cash equivalents	374		438
Accounts receivable
Customer accounts receivable	4,017		3,597
Customer allowance for credit losses	(442)		(366)
Customer accounts receivable, net	3,575		3,231
Other accounts receivable	1,320		1,469
Other allowance for credit losses	(79)		(71)
Other accounts receivable, net	1,241		1,398
Mark-to-market derivative assets	568		644
Unamortized energy contract assets	38		38
Inventories, net
Fossil fuel and emission allowances	205		297
Materials and supplies	1,427		1,425
Regulatory assets	1,269		1,228
Renewable energy credits	694		633
Assets held for sale	11		958
Other	1,687		1,609
Total current assets	12,997		12,562
Property, plant, and equipment (net of accumulated depreciation and amortization of $28,121 and $26,727 as of March 31, 2021 and December 31, 2020, respectively)	82,588		82,584
Deferred debits and other assets
Regulatory assets	8,810		8,759
Nuclear decommissioning trust funds	14,688		14,464
Investments	431		440
Goodwill	6,677		6,677
Mark-to-market derivative assets	491		555
Unamortized energy contract assets	285		294
Other	3,033		2,982
Total deferred debits and other assets	34,415		34,171
Total assets(a)	$	130,000	$	129,317

See the Combined Notes to Consolidated Financial Statements

12

EXELON CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities
Short-term borrowings	$	3,128	$	2,031
Long-term debt due within one year	2,281		1,819
Accounts payable	3,430		3,562
Accrued expenses	1,729		2,078
Payables to affiliates	5		5
Regulatory liabilities	663		581
Mark-to-market derivative liabilities	422		295
Unamortized energy contract liabilities	98		100
Renewable energy credit obligation	645		661
Liabilities held for sale	3		375
Other	1,176		1,264
Total current liabilities	13,580		12,771
Long-term debt	36,248		35,093
Long-term debt to financing trusts	390		390
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	13,129		13,035
Asset retirement obligations	12,405		12,300
Pension obligations	3,951		4,503
Non-pension postretirement benefit obligations	1,988		2,011
Spent nuclear fuel obligation	1,208		1,208
Regulatory liabilities	9,130		9,485
Mark-to-market derivative liabilities	453		473
Unamortized energy contract liabilities	217		238
Other	2,988		2,942
Total deferred credits and other liabilities	45,469		46,195
Total liabilities(a)	95,687		94,449
Commitments and contingencies
Shareholders’ equity
Common stock (No par value, 2,000 shares authorized, 977 shares and 976 shares outstanding at March 31, 2021 and December 31, 2020, respectively)	19,412		19,373
Treasury stock, at cost (2 shares at March 31, 2021 and December 31, 2020)	(123)		(123)
Retained earnings	16,072		16,735
Accumulated other comprehensive loss, net	(3,346)		(3,400)
Total shareholders’ equity	32,015		32,585
Noncontrolling interests	2,298		2,283
Total equity	34,313		34,868
Total liabilities and shareholders’ equity	$	130,000	$	129,317

__________

(a)Exelon’s consolidated assets include $9,985 million and $10,200 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,578 million and $3,598 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 16 — Variable Interest Entities for additional information.

See the Combined Notes to Consolidated Financial Statements

13

EXELON CORPORATION AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY

(Unaudited)

	Three Months Ended March 31, 2021
(In millions, shares in thousands)	Issued Shares	Common Stock		Treasury Stock		Retained Earnings		Accumulated Other Comprehensive Loss, net		Noncontrolling Interests		Total Shareholders' Equity
Balance, December 31, 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

	Three Months Ended March 31, 2020
(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, 2019	974,416	$	19,274	$	(123)	$	16,267	$	(3,194)	$	2,349	$	34,573
Net income (loss)	—	—		—		582		—		(206)		376
Long-term incentive plan activity	1,354	(4)		—		—		—		—		(4)
Employee stock purchase plan issuances	470	31		—		—		—		—		31
Changes in equity of noncontrolling interests	—	—		—		—		—		(9)		(9)
Sale of noncontrolling interests	—	2		—		—		—		—		2
Common stock dividends ($0.38/common share)	—	—		—		(374)		—		—		(374)
Other comprehensive income, net of income taxes	—	—		—		—		21		—		21
Balance, March 31, 2020	976,240	$	19,303	$	(123)	$	16,475	$	(3,173)	$	2,134	$	34,616

See the Combined Notes to Consolidated Financial Statements

14

EXELON GENERATION COMPANY, LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Operating revenues
Operating revenues	$	5,264	$	4,403
Operating revenues from affiliates	295		330
Total operating revenues	5,559		4,733
Operating expenses
Purchased power and fuel	4,610		2,710
Purchased power and fuel from affiliates	—		(6)
Operating and maintenance	856		1,121
Operating and maintenance from affiliates	145		142
Depreciation and amortization	940		304
Taxes other than income taxes	121		129
Total operating expenses	6,672		4,400
Gain on sales of assets and businesses	71		—
Operating (loss) income	(1,042)		333
Other income and (deductions)
Interest expense, net	(68)		(100)
Interest expense to affiliates	(4)		(9)
Other, net	167		(771)
Total other income and (deductions)	95		(880)
Loss before income taxes	(947)		(547)
Income taxes	(179)		(389)
Equity in losses of unconsolidated affiliates	(1)		(3)
Net loss	(769)		(161)
Net income (loss) attributable to noncontrolling interests	24		(206)
Net (loss) income attributable to membership interest	$	(793)	$	45
Comprehensive income, net of income taxes
Net loss	$	(769)	$	(161)
Other comprehensive income (loss), net of income taxes
Unrealized loss on cash flow hedges	—		(1)
Unrealized gain (loss) on foreign currency translation	1		(8)
Other comprehensive income (loss), net of income taxes	1		(9)
Comprehensive loss	(768)		(170)
Comprehensive income (loss) attributable to noncontrolling interests	24		(206)
Comprehensive (loss) income attributable to membership interest	$	(792)	$	36

See the Combined Notes to Consolidated Financial Statements

15

EXELON GENERATION COMPANY, LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Cash flows from operating activities
Net loss	$	(769)	$	(161)
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	1,346		661
Asset impairments	1		8
Gain on sales of assets and businesses	(71)		—
Deferred income taxes and amortization of investment tax credits	(123)		(329)
Net fair value changes related to derivatives	(178)		(127)
Net realized and unrealized (gains) losses on NDT funds	(118)		651
Unrealized loss on equity investments	23		—
Other non-cash operating activities	(202)		205
Changes in assets and liabilities:
Accounts receivable	(453)		787
Receivables from and payables to affiliates, net	59		34
Inventories	50		39
Accounts payable and accrued expenses	208		(614)
Option premiums received (paid), net	16		(38)
Collateral received (posted), net	270		(22)
Income taxes	(55)		(58)
Pension and non-pension postretirement benefit contributions	(205)		(232)
Other assets and liabilities	(1,411)		(184)
Net cash flows (used in) provided by operating activities	(1,612)		620
Cash flows from investing activities
Capital expenditures	(382)		(558)
Proceeds from NDT fund sales	2,908		1,183
Investment in NDT funds	(2,939)		(1,234)
Collection of DPP	1,574		—
Proceeds from sales of assets and businesses	680		—
Changes in Exelon intercompany money pool	—		(254)
Other investing activities	(2)		(8)
Net cash flows provided by (used in) investing activities	1,839		(871)
Cash flows from financing activities
Changes in short-term borrowings	997		275
Proceeds from short-term borrowings with maturities greater than 90 days	—		500
Issuance of long-term debt	1		1,502
Retirement of long-term debt	(35)		(1,028)
Changes in Exelon intercompany money pool	(285)		—
Distributions to member	(458)		(468)
Other financing activities	(12)		(8)
Net cash flows provided by financing activities	208		773
Increase in cash, restricted cash, and cash equivalents	435		522
Cash, restricted cash, and cash equivalents at beginning of period	327		449
Cash, restricted cash, and cash equivalents at end of period	$	762	$	971
Supplemental cash flow information
Decrease in capital expenditures not paid	$	(37)	$	(56)
Increase in DPP	1,339		—

See the Combined Notes to Consolidated Financial Statements

16

EXELON GENERATION COMPANY, LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
ASSETS
Current assets
Cash and cash equivalents	$	721	$	226
Restricted cash and cash equivalents	41		89
Accounts receivable
Customer accounts receivable	1,857		1,330
Customer allowance for credit losses	(65)		(32)
Customer accounts receivable, net	1,792		1,298
Other accounts receivable	348		352
Other accounts receivable, net	348		352
Mark-to-market derivative assets	569		644
Receivables from affiliates	106		153
Unamortized energy contract assets	38		38
Inventories, net
Fossil fuel and emission allowances	175		233
Materials and supplies	973		978
Renewable energy credits	676		621
Assets held for sale	11		958
Other	1,290		1,357
Total current assets	6,740		6,947
Property, plant, and equipment (net of accumulated depreciation and amortization of $14,355 and $13,370 as of March 31, 2021 and December 31, 2020, respectively)	21,311		22,214
Deferred debits and other assets
Nuclear decommissioning trust funds	14,688		14,464
Investments	178		184
Goodwill	47		47
Mark-to-market derivative assets	491		555
Prepaid pension asset	1,736		1,558
Unamortized energy contract assets	285		293
Deferred income taxes	15		6
Other	1,835		1,826
Total deferred debits and other assets	19,275		18,933
Total assets(a)	$	47,326	$	48,094

See the Combined Notes to Consolidated Financial Statements

17

EXELON GENERATION COMPANY, LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
LIABILITIES AND EQUITY
Current liabilities
Short-term borrowings	$	1,837	$	840
Long-term debt due within one year	699		197
Accounts payable	1,529		1,253
Accrued expenses	692		788
Payables to affiliates	125		107
Borrowings from Exelon intercompany money pool	—		285
Mark-to-market derivative liabilities	392		262
Unamortized energy contract liabilities	5		7
Renewable energy credit obligation	645		661
Liabilities held for sale	3		375
Other	371		444
Total current liabilities	6,298		5,219
Long-term debt	5,038		5,566
Long-term debt to affiliates	323		324
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	3,542		3,656
Asset retirement obligations	12,157		12,054
Non-pension postretirement benefit obligations	857		858
Spent nuclear fuel obligation	1,208		1,208
Payables to affiliates	2,865		3,017
Mark-to-market derivative liabilities	190		205
Unamortized energy contract liabilities	3		3
Other	1,405		1,308
Total deferred credits and other liabilities	22,227		22,309
Total liabilities(a)	33,886		33,418
Commitments and contingencies
Equity
Member’s equity
Membership interest	9,624		9,624
Undistributed earnings	1,554		2,805
Accumulated other comprehensive loss, net	(29)		(30)
Total member’s equity	11,149		12,399
Noncontrolling interests	2,291		2,277
Total equity	13,440		14,676
Total liabilities and equity	$	47,326	$	48,094

__________

(a)Generation’s consolidated assets include $9,967 million and $10,182 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,557 million and $3,572 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 16 — Variable Interest Entities for additional information.

See the Combined Notes to Consolidated Financial Statements

18

EXELON GENERATION COMPANY, LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(Unaudited)

	Three Months Ended March 31, 2021
	Member’s Equity
(In millions)	Membership Interest		Undistributed Earnings		Accumulated Other Comprehensive Loss, net		Noncontrolling Interests		Total Equity
Balance, December 31, 2020	$	9,624	$	2,805	$	(30)	$	2,277	$	14,676
Net (loss) income	—		(793)		—		24		(769)
Changes in equity of noncontrolling interests	—		—		—		(10)		(10)
Distributions to member	—		(458)		—		—		(458)
Other comprehensive income, net of income taxes	—		—		1		—		1
Balance, March 31, 2021	$	9,624	$	1,554	$	(29)	$	2,291	$	13,440

	Three Months Ended March 31, 2020
	Member’s Equity
(In millions)	Membership Interest		Undistributed Earnings		Accumulated Other Comprehensive Loss, net		Noncontrolling Interests		Total Equity
Balance, December 31, 2019	$	9,566	$	3,950	$	(32)	$	2,346	$	15,830
Net income (loss)	—		45		—		(206)		(161)
Changes in equity of noncontrolling interests	—		—		—		(11)		(11)
Sale of noncontrolling interests	2		—		—		—		2
Distributions to member	—		(468)		—		—		(468)
Other comprehensive loss, net of income taxes	—		—		(9)		—		(9)
Balance, March 31, 2020	$	9,568	$	3,527	$	(41)	$	2,129	$	15,183

See the Combined Notes to Consolidated Financial Statements

19

COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Operating revenues
Electric operating revenues	$	1,475	$	1,422
Revenues from alternative revenue programs	54		12
Operating revenues from affiliates	6		5
Total operating revenues	1,535		1,439
Operating expenses
Purchased power	442		389
Purchased power from affiliate	85		97
Operating and maintenance	245		243
Operating and maintenance from affiliates	71		74
Depreciation and amortization	292		273
Taxes other than income taxes	75		75
Total operating expenses	1,210		1,151
Operating income	325		288
Other income and (deductions)
Interest expense, net	(93)		(91)
Interest expense to affiliates	(3)		(3)
Other, net	7		10
Total other income and (deductions)	(89)		(84)
Income before income taxes	236		204
Income taxes	39		36
Net income	$	197	$	168
Comprehensive income	$	197	$	168

20

COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Cash flows from operating activities
Net income	$	197	$	168
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	292		273
Deferred income taxes and amortization of investment tax credits	63		42
Other non-cash operating activities	(9)		16
Changes in assets and liabilities:
Accounts receivable	23		9
Receivables from and payables to affiliates, net	(15)		(6)
Inventories	(1)		(2)
Accounts payable and accrued expenses	(176)		(147)
Collateral received (posted), net	5		3
Income taxes	(23)		(7)
Pension and non-pension postretirement benefit contributions	(171)		(143)
Other assets and liabilities	(159)		(132)
Net cash flows provided by operating activities	26		74
Cash flows from investing activities
Capital expenditures	(613)		(506)
Other investing activities	7		5
Net cash flows used in investing activities	(606)		(501)
Cash flows from financing activities
Changes in short-term borrowings	(188)		(130)
Issuance of long-term debt	700		1,000
Dividends paid on common stock	(127)		(125)
Contributions from parent	198		125
Other financing activities	(9)		(13)
Net cash flows provided by financing activities	574		857
(Decrease) increase in cash, restricted cash, and cash equivalents	(6)		430
Cash, restricted cash, and cash equivalents at beginning of period	405		403
Cash, restricted cash, and cash equivalents at end of period	$	399	$	833
Supplemental cash flow information
Decrease in capital expenditures not paid	$	(107)	$	(5)

See the Combined Notes to Consolidated Financial Statements

21

COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
ASSETS
Current assets
Cash and cash equivalents	$	86	$	83
Restricted cash and cash equivalents	270		279
Accounts receivable
Customer accounts receivable	626		656
Customer allowance for credit losses	(103)		(97)
Customer accounts receivable, net	523		559
Other accounts receivable	243		239
Other allowance for credit losses	(22)		(21)
Other accounts receivable, net	221		218
Receivables from affiliates	21		22
Inventories, net	170		170
Regulatory assets	294		279
Other	55		49
Total current assets	1,640		1,659
Property, plant, and equipment (net of accumulated depreciation and amortization of $5,811 and $5,672 as of March 31, 2021 and December 31, 2020, respectively)	24,840		24,557
Deferred debits and other assets
Regulatory assets	1,840		1,749
Investments	6		6
Goodwill	2,625		2,625
Receivables from affiliates	2,375		2,541
Prepaid pension asset	1,165		1,022
Other	334		307
Total deferred debits and other assets	8,345		8,250
Total assets	$	34,825	$	34,466

See the Combined Notes to Consolidated Financial Statements

22

COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities
Short-term borrowings	$	135	$	323
Long-term debt due within one year	350		350
Accounts payable	533		683
Accrued expenses	242		390
Payables to affiliates	80		96
Customer deposits	84		86
Regulatory liabilities	360		289
Mark-to-market derivative liabilities	31		33
Other	128		143
Total current liabilities	1,943		2,393
Long-term debt	9,324		8,633
Long-term debt to financing trust	205		205
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	4,427		4,341
Asset retirement obligations	127		126
Non-pension postretirement benefits obligations	177		173
Regulatory liabilities	6,172		6,403
Mark-to-market derivative liabilities	264		268
Other	589		595
Total deferred credits and other liabilities	11,756		11,906
Total liabilities	23,228		23,137
Commitments and contingencies
Shareholders’ equity
Common stock	1,588		1,588
Other paid-in capital	8,483		8,285
Retained deficit unappropriated	(1,639)		(1,639)
Retained earnings appropriated	3,165		3,095
Total shareholders’ equity	11,597		11,329
Total liabilities and shareholders’ equity	$	34,825	$	34,466

See the Combined Notes to Consolidated Financial Statements

23

COMMONWEALTH EDISON COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY

(Unaudited)

	Three Months Ended March 31, 2021
(In millions)	Common Stock		Other Paid-In Capital		Retained Deficit Unappropriated		Retained Earnings Appropriated		Total Shareholders’ Equity
Balance, December 31, 2020	$	1,588	$	8,285	$	(1,639)	$	3,095	$	11,329
Net income	—		—		197		—		197
Appropriation of retained earnings for future dividends	—		—		(197)		197		—
Common stock dividends	—		—		—		(127)		(127)
Contributions from parent	—		198		—		—		198
Balance, March 31, 2021	$	1,588	$	8,483	$	(1,639)	$	3,165	$	11,597
	Three Months Ended March 31, 2020
(In millions)	Common Stock		Other Paid-In Capital		Retained Deficit Unappropriated		Retained Earnings Appropriated		Total Shareholders’ Equity
Balance, December 31, 2019	$	1,588	$	7,572	$	(1,639)	$	3,156	$	10,677
Net income	—		—		168		—		168
Appropriation of retained earnings for future dividends	—		—		(168)		168		—
Common stock dividends	—		—		—		(125)		(125)
Contributions from parent	—		125		—		—		125
Balance, March 31, 2020	$	1,588	$	7,697	$	(1,639)	$	3,199	$	10,845

See the Combined Notes to Consolidated Financial Statements

24

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Operating revenues
Electric operating revenues	$	649	$	600
Natural gas operating revenues	228		209
Revenues from alternative revenue programs	10		2
Operating revenues from affiliates	2		2
Total operating revenues	889		813
Operating expenses
Purchased power	189		164
Purchased fuel	86		83
Purchased power from affiliate	41		36
Operating and maintenance	193		179
Operating and maintenance from affiliates	41		38
Depreciation and amortization	86		86
Taxes other than income taxes	43		39
Total operating expenses	679		625
Operating income	210		188
Other income and (deductions)
Interest expense, net	(35)		(33)
Interest expense to affiliates	(3)		(3)
Other, net	5		3
Total other income and (deductions)	(33)		(33)
Income before income taxes	177		155
Income taxes	10		15
Net income	$	167	$	140
Comprehensive income	$	167	$	140

See the Combined Notes to Consolidated Financial Statements

25

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Cash flows from operating activities
Net income	$	167	$	140
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	86		86
Deferred income taxes and amortization of investment tax credits	6		2
Other non-cash operating activities	12		22
Changes in assets and liabilities:
Accounts receivable	(5)		14
Receivables from and payables to affiliates, net	(2)		(3)
Inventories	13		15
Accounts payable and accrued expenses	(36)		(45)
Income taxes	3		14
Pension and non-pension postretirement benefit contributions	(16)		(16)
Other assets and liabilities	(103)		(84)
Net cash flows provided by operating activities	125		145
Cash flows from investing activities
Capital expenditures	(295)		(259)
Changes in Exelon intercompany money pool	(48)		(22)
Other investing activities	1		1
Net cash flows used in investing activities	(342)		(280)
Cash flows from financing activities
Issuance of long-term debt	375		—
Changes in Exelon intercompany money pool	(40)		—
Dividends paid on common stock	(85)		(85)
Contributions from parent	—		231
Other financing activities	(4)		—
Net cash flows provided by financing activities	246		146
Increase in cash, restricted cash, and cash equivalents	29		11
Cash, restricted cash, and cash equivalents at beginning of period	26		27
Cash, restricted cash, and cash equivalents at end of period	$	55	$	38
Supplemental cash flow information
Decrease in capital expenditures not paid	$	(44)	$	(11)

See the Combined Notes to Consolidated Financial Statements

26

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
ASSETS
Current assets
Cash and cash equivalents	$	48	$	19
Restricted cash and cash equivalents	7		7
Accounts receivable
Customer accounts receivable	499		511
Customer allowance for credit losses	(130)		(116)
Customer accounts receivable, net	369		395
Other accounts receivable	140		130
Other allowance for credit losses	(11)		(8)
Other accounts receivable, net	129		122
Receivables from affiliates	—		2
Receivable from Exelon intercompany money pool	48		—
Inventories, net
Fossil fuel	15		33
Materials and supplies	43		38
Prepaid utility taxes	103		—
Regulatory assets	29		25
Other	22		21
Total current assets	813		662
Property, plant, and equipment (net of accumulated depreciation and amortization of $3,897 and $3,843 as of March 31, 2021 and December 31, 2020, respectively)	10,352		10,181
Deferred debits and other assets
Regulatory assets	828		776
Investments	30		30
Receivables from affiliates	490		475
Prepaid pension asset	389		375
Other	35		32
Total deferred debits and other assets	1,772		1,688
Total assets	$	12,937	$	12,531

See the Combined Notes to Consolidated Financial Statements

27

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities
Long-term debt due within one year	$	300	$	300
Accounts payable	431		479
Accrued expenses	100		129
Payables to affiliates	46		50
Borrowings from Exelon intercompany money pool	—		40
Customer deposits	54		59
Regulatory liabilities	127		121
Other	31		30
Total current liabilities	1,089		1,208
Long-term debt	3,825		3,453
Long-term debt to financing trusts	184		184
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	2,297		2,242
Asset retirement obligations	29		29
Non-pension postretirement benefits obligations	286		286
Regulatory liabilities	519		503
Other	93		93
Total deferred credits and other liabilities	3,224		3,153
Total liabilities	8,322		7,998
Commitments and contingencies
Shareholder’s equity
Common stock	3,014		3,014
Retained earnings	1,601		1,519
Total shareholder’s equity	4,615		4,533
Total liabilities and shareholder's equity	$	12,937	$	12,531

See the Combined Notes to Consolidated Financial Statements

28

PECO ENERGY COMPANY AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER’S EQUITY

(Unaudited)

	Three Months Ended March 31, 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
	Three Months Ended March 31, 2020
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2019	$	2,766	$	1,412	$	4,178
Net income	—		140		140
Common stock dividends	—		(85)		(85)
Contributions from parent	231		—		231
Balance, March 31, 2020	$	2,997	$	1,467	$	4,464

See the Combined Notes to Consolidated Financial Statements

29

BALTIMORE GAS AND ELECTRIC COMPANY

STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Operating revenues
Electric operating revenues	$	620	$	595
Natural gas operating revenues	330		300
Revenues from alternative revenue programs	18		36
Operating revenues from affiliates	6		6
Total operating revenues	974		937
Operating expenses
Purchased power	162		114
Purchased fuel	99		76
Purchased power and fuel from affiliate	70		98
Operating and maintenance	152		146
Operating and maintenance from affiliates	45		42
Depreciation and amortization	152		143
Taxes other than income taxes	72		69
Total operating expenses	752		688
Operating income	222		249
Other income and (deductions)
Interest expense, net	(34)		(32)
Other, net	8		5
Total other income and (deductions)	(26)		(27)
Income before income taxes	196		222
Income taxes	(13)		41
Net income	$	209	$	181
Comprehensive income	$	209	$	181

See the Combined Notes to Consolidated Financial Statements

30

BALTIMORE GAS AND ELECTRIC COMPANY

STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Cash flows from operating activities
Net income	$	209	$	181
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	152		143
Deferred income taxes and amortization of investment tax credits	(4)		33
Other non-cash operating activities	2		(8)
Changes in assets and liabilities:
Accounts receivable	12		(28)
Receivables from and payables to affiliates, net	(15)		(13)
Inventories	9		20
Accounts payable and accrued expenses	(59)		(9)
Income taxes	(9)		7
Pension and non-pension postretirement benefit contributions	(65)		(64)
Other assets and liabilities	(103)		10
Net cash flows provided by operating activities	129		272
Cash flows from investing activities
Capital expenditures	(336)		(283)
Other investing activities	2		(6)
Net cash flows used in investing activities	(334)		(289)
Cash flows from financing activities
Changes in short-term borrowings	156		66
Dividends paid on common stock	(74)		(62)
Net cash flows provided by financing activities	82		4
Decrease in cash, restricted cash, and cash equivalents	(123)		(13)
Cash, restricted cash, and cash equivalents at beginning of period	145		25
Cash, restricted cash, and cash equivalents at end of period	$	22	$	12
Supplemental cash flow information
Decrease in capital expenditures not paid	$	(80)	$	(35)

See the Combined Notes to Consolidated Financial Statements

31

BALTIMORE GAS AND ELECTRIC COMPANY

BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
ASSETS
Current assets
Cash and cash equivalents	$	21	$	144
Restricted cash and cash equivalents	1		1
Accounts receivable
Customer accounts receivable	476		487
Customer allowance for credit losses	(43)		(35)
Customer accounts receivable, net	433		452
Other accounts receivable	125		117
Other allowance for credit losses	(9)		(9)
Other accounts receivable, net	116		108
Receivables from affiliates	—		3
Inventories, net
Fossil fuel	12		25
Materials and supplies	45		41
Prepaid utility taxes	43		—
Regulatory assets	179		168
Other	9		6
Total current assets	859		948
Property, plant, and equipment (net of accumulated depreciation and amortization of $4,115 and $4,034 as of March 31, 2021 and December 31, 2020, respectively)	10,026		9,872
Deferred debits and other assets
Regulatory assets	481		481
Investments	10		10
Prepaid pension asset	314		270
Other	69		69
Total deferred debits and other assets	874		830
Total assets	$	11,759	$	11,650

See the Combined Notes to Consolidated Financial Statements

32

BALTIMORE GAS AND ELECTRIC COMPANY

BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities
Short-term borrowings	$	156	$	—
Long-term debt due within one year	300		300
Accounts payable	266		346
Accrued expenses	142		205
Payables to affiliates	43		61
Customer deposits	105		110
Regulatory liabilities	41		30
Other	83		91
Total current liabilities	1,136		1,143
Long-term debt	3,365		3,364
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	1,609		1,521
Asset retirement obligations	24		23
Non-pension postretirement benefits obligations	182		189
Regulatory liabilities	1,016		1,109
Other	95		104
Total deferred credits and other liabilities	2,926		2,946
Total liabilities	7,427		7,453
Commitments and contingencies
Shareholder's equity
Common stock	2,318		2,318
Retained earnings	2,014		1,879
Total shareholder's equity	4,332		4,197
Total liabilities and shareholder's equity	$	11,759	$	11,650

See the Combined Notes to Consolidated Financial Statements

33

BALTIMORE GAS AND ELECTRIC COMPANY

STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY

(Unaudited)

	Three Months Ended March 31, 2021
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2020	$	2,318	$	1,879	$	4,197
Net income	—		209		209
Common stock dividends	—		(74)		(74)
Balance, March 31, 2021	$	2,318	$	2,014	$	4,332
	Three Months Ended March 31, 2020
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2019	$	1,907	$	1,776	$	3,683
Net income	—		181		181
Common stock dividends	—		(62)		(62)
Balance, March 31, 2020	$	1,907	$	1,895	$	3,802

See the Combined Notes to Consolidated Financial Statements

34

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Operating revenues
Electric operating revenues	$	1,124	$	1,086
Natural gas operating revenues	71		64
Revenues from alternative revenue programs	46		18
Operating revenues from affiliates	3		3
Total operating revenues	1,244		1,171
Operating expenses
Purchased power	348		300
Purchased fuel	33		31
Purchased power from affiliates	98		104
Operating and maintenance	216		219
Operating and maintenance from affiliates	40		38
Depreciation and amortization	210		194
Taxes other than income taxes	113		114
Total operating expenses	1,058		1,000
Gain on sales of assets	—		2
Operating income	186		173
Other income and (deductions)
Interest expense, net	(67)		(67)
Other, net	17		13
Total other income and (deductions)	(50)		(54)
Income before income taxes	136		119
Income taxes	8		11
Net income	$	128	$	108
Comprehensive income	$	128	$	108

See the Combined Notes to Consolidated Financial Statements

35

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Cash flows from operating activities
Net income	$	128	$	108
Adjustments to reconcile net income to net cash flows from operating activities:
Depreciation and amortization	210		194
Deferred income taxes and amortization of investment tax credits	4		(4)
Other non-cash operating activities	(25)		7
Changes in assets and liabilities:
Accounts receivable	56		36
Receivables from and payables to affiliates, net	(18)		(17)
Inventories	5		8
Accounts payable and accrued expenses	(24)		(16)
Income taxes	3		15
Pension and non-pension postretirement benefit contributions	(36)		(27)
Other assets and liabilities	(94)		(72)
Net cash flows provided by operating activities	209		232
Cash flows from investing activities
Capital expenditures	(456)		(376)
Other investing activities	1		1
Net cash flows used in investing activities	(455)		(375)
Cash flows from financing activities
Changes in short-term borrowings	(368)		(100)
Issuance of long-term debt	625		150
Retirement of long-term debt	(44)		(6)
Changes in Exelon intercompany money pool	3		7
Distributions to member	(81)		(134)
Contributions from member	560		144
Other financing activities	(5)		(1)
Net cash flows provided by financing activities	690		60
Increase (decrease) in cash, restricted cash, and cash equivalents	444		(83)
Cash, restricted cash, and cash equivalents at beginning of period	160		181
Cash, restricted cash, and cash equivalents at end of period	$	604	$	98
Supplemental cash flow information
Decrease in capital expenditures not paid	$	(33)	$	(57)

See the Combined Notes to Consolidated Financial Statements

36

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
ASSETS
Current assets
Cash and cash equivalents	$	558	$	111
Restricted cash and cash equivalents	37		39
Accounts receivable
Customer accounts receivable	557		611
Customer allowance for credit losses	(101)		(86)
Customer accounts receivable, net	456		525
Other accounts receivable	261		260
Other allowance for credit losses	(37)		(33)
Other accounts receivable, net	224		227
Receivables from affiliates	—		8
Inventories, net
Fossil fuel	3		6
Materials and supplies	196		198
Regulatory assets	450		440
Other	52		45
Total current assets	1,976		1,599
Property, plant, and equipment (net of accumulated depreciation and amortization of $1,930 and $1,811 as of March 31, 2021 and December 31, 2020, respectively)	15,651		15,377
Deferred debits and other assets
Regulatory assets	1,912		1,933
Investments	141		140
Goodwill	4,005		4,005
Prepaid pension asset	383		365
Deferred income taxes	9		10
Other	310		307
Total deferred debits and other assets	6,760		6,760
Total assets(a)	$	24,387	$	23,736

See the Combined Notes to Consolidated Financial Statements

37

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
LIABILITIES AND MEMBER'S EQUITY
Current liabilities
Short-term borrowings	$	—	$	368
Long-term debt due within one year	304		347
Accounts payable	503		539
Accrued expenses	279		299
Payables to affiliates	78		104
Borrowings from Exelon intercompany money pool	24		21
Customer deposits	96		106
Regulatory liabilities	130		137
Unamortized energy contract liabilities	92		92
Other	137		141
Total current liabilities	1,643		2,154
Long-term debt	7,273		6,659
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	2,481		2,439
Asset retirement obligations	59		59
Non-pension postretirement benefit obligations	80		86
Regulatory liabilities	1,391		1,438
Unamortized energy contract liabilities	214		235
Other	595		622
Total deferred credits and other liabilities	4,820		4,879
Total liabilities(a)	13,736		13,692
Commitments and contingencies
Member's equity
Membership interest	10,672		10,112
Undistributed losses	(21)		(68)
Total member's equity	10,651		10,044
Total liabilities and member's equity	$	24,387	$	23,736

__________

(a)PHI’s consolidated total assets include $18 million at both March 31, 2021 and December 31, 2020 of PHI's consolidated VIE that can only be used to settle the liabilities of the VIE. PHI’s consolidated total liabilities include $21 million and $26 million at March 31, 2021 and December 31, 2020, respectively, of PHI's consolidated VIE for which the VIE creditors do not have recourse to PHI. See Note 16 — Variable Interest Entities for additional information.

See the Combined Notes to Consolidated Financial Statements

38

PEPCO HOLDINGS LLC AND SUBSIDIARY COMPANIES

CONSOLIDATED STATEMENTS OF CHANGES IN MEMBER'S EQUITY

(Unaudited)

	Three Months Ended March 31, 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

	Three Months Ended March 31, 2020
(In millions)	Membership Interest		Undistributed (Losses)/Earnings		Total Member's Equity
Balance, December 31, 2019	$	9,618	$	(10)	$	9,608
Net income	—		108		108
Distributions to member	—		(134)		(134)
Contributions from member	144		—		144
Balance, March 31, 2020	$	9,762	$	(36)	$	9,726

See the Combined Notes to Consolidated Financial Statements

39

POTOMAC ELECTRIC POWER COMPANY

STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Operating revenues
Electric operating revenues	$	526	$	528
Revenues from alternative revenue programs	26		15
Operating revenues from affiliates	1		1
Total operating revenues	553		544
Operating expenses
Purchased power	92		85
Purchased power from affiliate	74		79
Operating and maintenance	56		60
Operating and maintenance from affiliates	52		51
Depreciation and amortization	102		95
Taxes other than income taxes	90		92
Total operating expenses	466		462
Operating income	87		82
Other income and (deductions)
Interest expense, net	(34)		(34)
Other, net	12		9
Total other income and (deductions)	(22)		(25)
Income before income taxes	65		57
Income taxes	6		5
Net income	$	59	$	52
Comprehensive income	$	59	$	52

See the Combined Notes to Consolidated Financial Statements

40

POTOMAC ELECTRIC POWER COMPANY

STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Cash flows from operating activities
Net income	$	59	$	52
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	102		95
Deferred income taxes and amortization of investment tax credits	4		(2)
Other non-cash operating activities	(25)		(11)
Changes in assets and liabilities:
Accounts receivable	26		14
Receivables from and payables to affiliates, net	(9)		(11)
Inventories	1		3
Accounts payable and accrued expenses	—		6
Income taxes	2		6
Pension and non-pension postretirement benefit contributions	(5)		(4)
Other assets and liabilities	(58)		(38)
Net cash flows provided by operating activities	97		110
Cash flows from investing activities
Capital expenditures	(220)		(180)
Changes in PHI intercompany money pool	—		(114)
Other investing activities	1		(4)
Net cash flows used in investing activities	(219)		(298)
Cash flows from financing activities
Changes in short-term borrowings	(35)		(82)
Issuance of long-term debt	150		150
Dividends paid on common stock	(28)		(28)
Contributions from parent	138		137
Other financing activities	(1)		(1)
Net cash flows provided by financing activities	224		176
Increase (decrease) in cash, restricted cash, and cash equivalents	102		(12)
Cash, restricted cash, and cash equivalents at beginning of period	65		63
Cash, restricted cash, and cash equivalents at end of period	$	167	$	51
Supplemental cash flow information
Decrease in capital expenditures not paid	$	(16)	$	(43)

See the Combined Notes to Consolidated Financial Statements

41

POTOMAC ELECTRIC POWER COMPANY

BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
ASSETS
Current assets
Cash and cash equivalents	$	134	$	30
Restricted cash and cash equivalents	33		35
Accounts receivable
Customer accounts receivable	252		279
Customer allowance for credit losses	(41)		(32)
Customer accounts receivable, net	211		247
Other accounts receivable	138		131
Other allowance for credit losses	(15)		(13)
Other accounts receivable, net	123		118
Receivables from affiliates	—		2
Inventories, net	110		111
Regulatory assets	224		214
Other	19		13
Total current assets	854		770
Property, plant, and equipment (net of accumulated depreciation and amortization of $3,746 and $3,697 as of March 31, 2021 and December 31, 2020, respectively)	7,606		7,456
Deferred debits and other assets
Regulatory assets	563		570
Investments	116		115
Prepaid pension asset	283		284
Other	71		69
Total deferred debits and other assets	1,033		1,038
Total assets	$	9,493	$	9,264

See the Combined Notes to Consolidated Financial Statements

42

POTOMAC ELECTRIC POWER COMPANY

BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities
Short-term borrowings	$	—	$	35
Long-term debt due within one year	4		3
Accounts payable	213		226
Accrued expenses	165		164
Payables to affiliates	44		55
Customer deposits	45		51
Regulatory liabilities	39		46
Merger related obligation	33		33
Current portion of DC PLUG obligation	30		30
Other	30		31
Total current liabilities	603		674
Long-term debt	3,313		3,162
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	1,209		1,189
Asset retirement obligations	39		39
Non-pension postretirement benefit obligations	9		13
Regulatory liabilities	624		644
Other	324		340
Total deferred credits and other liabilities	2,205		2,225
Total liabilities	6,121		6,061
Commitments and contingencies
Shareholder's equity
Common stock	2,196		2,058
Retained earnings	1,176		1,145
Total shareholder's equity	3,372		3,203
Total liabilities and shareholder's equity	$	9,493	$	9,264

See the Combined Notes to Consolidated Financial Statements

43

POTOMAC ELECTRIC POWER COMPANY

STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY

(Unaudited)

	Three Months Ended March 31, 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

	Three Months Ended March 31, 2020
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2019	$	1,796	$	1,111	$	2,907
Net income	—		52		52
Common stock dividends	—		(28)		(28)
Contributions from parent	137		—		137
Balance, March 31, 2020	$	1,933	$	1,135	$	3,068

See the Combined Notes to Consolidated Financial Statements

44

DELMARVA POWER & LIGHT COMPANY

STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Operating revenues
Electric operating revenues	$	300	$	283
Natural gas operating revenues	71		64
Revenues from alternative revenue programs	9		1
Operating revenues from affiliates	2		2
Total operating revenues	382		350
Operating expenses
Purchased power	103		88
Purchased fuel	33		31
Purchased power from affiliates	20		22
Operating and maintenance	44		42
Operating and maintenance from affiliates	39		37
Depreciation and amortization	53		48
Taxes other than income taxes	17		16
Total operating expenses	309		284
Operating income	73		66
Other income and (deductions)
Interest expense, net	(15)		(16)
Other, net	3		2
Total other income and (deductions)	(12)		(14)
Income before income taxes	61		52
Income taxes	5		7
Net income	$	56	$	45
Comprehensive income	$	56	$	45

See the Combined Notes to Consolidated Financial Statements

45

DELMARVA POWER & LIGHT COMPANY

STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Cash flows from operating activities
Net income	$	56	$	45
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	53		48
Deferred income taxes and amortization of investment tax credits	2		—
Other non-cash operating activities	(1)		2
Changes in assets and liabilities:
Accounts receivable	15		14
Receivables from and payables to affiliates, net	(11)		(9)
Inventories	2		3
Accounts payable and accrued expenses	11		4
Income taxes	3		7
Other assets and liabilities	(26)		(10)
Net cash flows provided by operating activities	104		104
Cash flows from investing activities
Capital expenditures	(112)		(95)
Other investing activities	—		(4)
Net cash flows used in investing activities	(112)		(99)
Cash flows from financing activities
Changes in short-term borrowings	(146)		(2)
Issuance of long-term debt	125		—
Changes in PHI intercompany money pool	—		37
Dividends paid on common stock	(40)		(52)
Contributions from parent	120		6
Other financing activities	(2)		—
Net cash flows provided by (used in) financing activities	57		(11)
Increase (decrease) in cash and cash equivalents	49		(6)
Cash and cash equivalents at beginning of period	15		13
Cash and cash equivalents at end of period	$	64	$	7
Supplemental cash flow information
Decrease in capital expenditures not paid	$	(15)	$	(9)

See the Combined Notes to Consolidated Financial Statements

46

DELMARVA POWER & LIGHT COMPANY

BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
ASSETS
Current assets
Cash and cash equivalents	$	64	$	15
Accounts receivable
Customer accounts receivable	160		176
Customer allowance for credit losses	(25)		(22)
Customer accounts receivable, net	135		154
Other accounts receivable	66		68
Other allowance for credit losses	(10)		(9)
Other accounts receivable, net	56		59
Receivables from affiliates	—		1
Inventories, net
Fossil fuel	2		6
Materials and supplies	53		51
Prepaid utility taxes	10		11
Regulatory assets	65		58
Renewable energy credits	14		10
Other	2		3
Total current assets	401		368
Property, plant, and equipment (net of accumulated depreciation and amortization of $1,563 and $1,533 as of March 31, 2021 and December 31, 2020, respectively)	4,368		4,314
Deferred debits and other assets
Regulatory assets	226		222
Goodwill	8		8
Prepaid pension asset	161		162
Other	68		66
Total deferred debits and other assets	463		458
Total assets	$	5,232	$	5,140

See the Combined Notes to Consolidated Financial Statements

47

DELMARVA POWER & LIGHT COMPANY

BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities
Short-term borrowings	$	—	$	146
Long-term debt due within one year	82		82
Accounts payable	119		126
Accrued expenses	49		46
Payables to affiliates	24		36
Customer deposits	30		32
Regulatory liabilities	49		47
Other	19		20
Total current liabilities	372		535
Long-term debt	1,720		1,595
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	734		715
Asset retirement obligations	14		14
Non-pension postretirement benefits obligations	14		15
Regulatory liabilities	474		493
Other	92		97
Total deferred credits and other liabilities	1,328		1,334
Total liabilities	3,420		3,464
Commitments and contingencies
Shareholder's equity
Common stock	1,209		1,089
Retained earnings	603		587
Total shareholder's equity	1,812		1,676
Total liabilities and shareholder's equity	$	5,232	$	5,140

See the Combined Notes to Consolidated Financial Statements

48

DELMARVA POWER & LIGHT COMPANY

STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY

(Unaudited)

	Three Months Ended March 31, 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

	Three Months Ended March 31, 2020
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2019	$	977	$	603	$	1,580
Net income	—		45		45
Common stock dividends	—		(52)		(52)
Contributions from parent	6		—		6
Balance, March 31, 2020	$	983	$	596	$	1,579

See the Combined Notes to Consolidated Financial Statements

49

ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Operating revenues
Electric operating revenues	$	298	$	274
Revenues from alternative revenue programs	11		1
Operating revenues from affiliates	1		1
Total operating revenues	310		276
Operating expenses
Purchased power	153		126
Purchased power from affiliate	4		2
Operating and maintenance	42		45
Operating and maintenance from affiliates	34		33
Depreciation and amortization	47		43
Taxes other than income taxes	2		2
Total operating expenses	282		251
Gain on sale of assets	—		2
Operating income	28		27
Other income and (deductions)
Interest expense, net	(15)		(14)
Interest expense to affiliates, net	—		(1)
Other, net	1		2
Total other income and (deductions)	(14)		(13)
Income before income taxes	14		14
Income taxes	—		1
Net income	$	14	$	13
Comprehensive income	$	14	$	13

See the Combined Notes to Consolidated Financial Statements

50

ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
(In millions)	2021		2020
Cash flows from operating activities
Net income	$	14	$	13
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation and amortization	47		43
Deferred income taxes and amortization of investment tax credits	(1)		(1)
Other non-cash operating activities	(7)		4
Changes in assets and liabilities:
Accounts receivable	13		11
Receivables from and payables to affiliates, net	1		3
Inventories	3		2
Accounts payable and accrued expenses	(11)		3
Income taxes	1		2
Pension and non-pension postretirement benefit contributions	(3)		(2)
Other assets and liabilities	(3)		(22)
Net cash flows provided by operating activities	54		56
Cash flows from investing activities
Capital expenditures	(123)		(101)
Other investing activities	—		6
Net cash flows used in investing activities	(123)		(95)
Cash flows from financing activities
Changes in short-term borrowings	(187)		(16)
Issuance of long-term debt	350		—
Retirement of long-term debt	(44)		(5)
Changes in PHI intercompany money pool	—		77
Dividends paid on common stock	(14)		(23)
Contributions from parent	303		1
Other financing activities	(3)		—
Net cash flows provided by financing activities	405		34
Increase (decrease) in cash, restricted cash, and cash equivalents	336		(5)
Cash, restricted cash, and cash equivalents at beginning of period	30		28
Cash, restricted cash, and cash equivalents at end of period	$	366	$	23
Supplemental cash flow information
Decrease in capital expenditures not paid	$	(2)	$	(4)

See the Combined Notes to Consolidated Financial Statements

51

ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
ASSETS
Current assets
Cash and cash equivalents	$	353	$	17
Restricted cash and cash equivalents	4		3
Accounts receivable
Customer accounts receivable	146		156
Customer allowance for credit losses	(35)		(32)
Customer accounts receivable, net	111		124
Other accounts receivable	69		72
Other allowance for credit losses	(12)		(11)
Other accounts receivable, net	57		61
Receivables from affiliates	1		6
Inventories, net	34		37
Regulatory assets	69		75
Other	2		3
Total current assets	631		326
Property, plant, and equipment (net of accumulated depreciation and amortization of $1,329 and $1,303 as of March 31, 2021 and December 31, 2020, respectively)	3,552		3,475
Deferred debits and other assets
Regulatory assets	407		395
Prepaid pension asset	39		40
Other	50		50
Total deferred debits and other assets	496		485
Total assets(a)	$	4,679	$	4,286

See the Combined Notes to Consolidated Financial Statements

52

ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY

CONSOLIDATED BALANCE SHEETS

(Unaudited)

(In millions)	March 31, 2021		December 31, 2020
LIABILITIES AND SHAREHOLDER'S EQUITY
Current liabilities
Short-term borrowings	$	—	$	187
Long-term debt due within one year	218		261
Accounts payable	162		177
Accrued expenses	48		46
Payables to affiliates	27		31
Customer deposits	21		23
Regulatory liabilities	41		44
Other	9		11
Total current liabilities	526		780
Long-term debt	1,500		1,152
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits	629		624
Non-pension postretirement benefit obligations	16		17
Regulatory liabilities	266		274
Other	48		48
Total deferred credits and other liabilities	959		963
Total liabilities(a)	2,985		2,895
Commitments and contingencies
Shareholder's equity
Common stock	1,574		1,271
Retained earnings	120		120
Total shareholder's equity	1,694		1,391
Total liabilities and shareholder's equity	$	4,679	$	4,286

__________

(a)ACE’s consolidated total assets include $13 million at both March 31, 2021 and December 31, 2020, of ACE's consolidated VIE that can only be used to settle the liabilities of the VIE. ACE’s consolidated total liabilities include $16 million and $21 million at March 31, 2021 and December 31, 2020, respectively, of ACE's consolidated VIE for which the VIE creditors do not have recourse to ACE. See Note 16 — Variable Interest Entities for additional information.

See the Combined Notes to Consolidated Financial Statements

53

ATLANTIC CITY ELECTRIC COMPANY AND SUBSIDIARY COMPANY

CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDER'S EQUITY

(Unaudited)

	Three Months Ended March 31, 2021
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2020	$	1,271	$	120	$	1,391
Net income	—		14		14
Common stock dividends	—		(14)		(14)
Contributions from parent	303		—		303
Balance, March 31, 2021	$	1,574	$	120	$	1,694

	Three Months Ended March 31, 2020
(In millions)	Common Stock		Retained Earnings		Total Shareholder's Equity
Balance, December 31, 2019	$	1,154	$	122	$	1,276
Net income	—		13		13
Common stock dividends	—		(23)		(23)
Contributions from parent	1		—		1
Balance, March 31, 2020	$	1,155	$	112	$	1,267

See the Combined Notes to Consolidated Financial Statements

54

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 (All Registrants)

Exelon is a utility services holding company engaged in the generation, delivery and marketing of energy through Generation and the energy distribution and transmission businesses through ComEd, PECO, BGE, Pepco, DPL, and ACE.

Name of Registrant	Business	Service Territories
Exelon Generation Company, LLC	Generation, physical delivery and marketing of power across multiple geographical regions through its customer-facing business, Constellation, which sells electricity to both wholesale and retail customers. Generation also sells natural gas, renewable energy, and other energy-related products and services.	Five reportable segments: Mid-Atlantic, Midwest, New York, ERCOT, and Other Power Regions
Commonwealth Edison Company	Purchase and regulated retail sale of electricity	Northern Illinois, including the City of Chicago
	Transmission and distribution of electricity to retail customers
PECO Energy Company	Purchase and regulated retail sale of electricity and natural gas	Southeastern Pennsylvania, including the City of Philadelphia (electricity)
	Transmission and distribution of electricity and distribution of natural gas to retail customers	Pennsylvania counties surrounding the City of Philadelphia (natural gas)
Baltimore Gas and Electric Company	Purchase and regulated retail sale of electricity and natural gas	Central Maryland, including the City of Baltimore (electricity and natural gas)
	Transmission and distribution of electricity and distribution of natural gas to retail customers
Pepco Holdings LLC	Utility services holding company engaged, through its reportable segments Pepco, DPL, and ACE	Service Territories of Pepco, DPL, and ACE
Potomac Electric  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 (All Registrants)

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.

Through its business services subsidiary, BSC, Exelon provides its subsidiaries with a variety of support services at cost, including legal, human resources, financial, information technology, and supply management services. PHI also has a business services subsidiary, PHISCO, which provides a variety of support services at cost, including legal, accounting, engineering, customer operations, distribution and transmission planning, asset management, system operations, and power procurement, to PHI operating companies. The costs of BSC and PHISCO are directly charged or allocated to the applicable subsidiaries. The results of Exelon’s corporate operations are presented as “Other” within the consolidated financial statements and include intercompany eliminations unless otherwise disclosed.

The accompanying consolidated financial statements as of March 31, 2021 and for the three months ended March 31, 2021 and 2020 are unaudited but, in the opinion of the management of each Registrant include all adjustments that are considered necessary for a fair statement of the Registrants’ respective financial statements in accordance with GAAP. All adjustments are of a normal, recurring nature, except as otherwise disclosed. The

55

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

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

Note 1 — Significant Accounting Policies

December 31, 2020 Consolidated Balance Sheets were derived from audited financial statements. 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, 2021. 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.

2. Mergers, Acquisitions, and Dispositions (Exelon and Generation)

CENG Put Option (Exelon and Generation)

Generation owns a 50.01% membership interest in CENG, a joint venture with EDF, which wholly owns the Calvert Cliffs and Ginna nuclear stations and Nine Mile Point Unit 1, in addition to an 82% undivided ownership interest in Nine Mile Point Unit 2. CENG is 100% consolidated in Exelon's and Generation's financial statements. See Note 16 — Variable Interest Entities for additional information.

On April 1, 2014, Generation and EDF entered into various agreements including a NOSA, an amended LLC Operating Agreement, an Employee Matters Agreement, and a Put Option Agreement, among others. Under the amended LLC Operating Agreement, CENG made a $400 million special distribution to EDF and committed to make preferred distributions to Generation until Generation has received aggregate distributions of $400 million plus a return of 8.50% per annum.

Under the terms of the Put Option Agreement, EDF has the option to sell its 49.99% equity interest in CENG to Generation exercisable beginning on January 1, 2016 and thereafter until June 30, 2022. The Put Option Agreement’s terms also provide that in the event the put closing has not been completed prior to the 18-month anniversary of the exercise date, EDF may withdraw its exercise notice. In the event of a withdrawal, EDF retains the right to exercise the put option until the later of June 30, 2022 and 18 months following the date of withdrawal, but in no event later than January 1, 2024. EDF is not entitled to this withdrawal right in the event it breaches any provision of the Put Option Agreement that results in the failure of the put to close on or before the 18-month anniversary of the exercise date.

The Put Option Agreement provides that the purchase price is to be determined by agreement of the parties, or absent such agreement, by a third-party arbitration process. The third parties determining fair market value of EDF’s 49.99% interest are to take into consideration all rights and obligations under the LLC Operating Agreement and Employee Matters Agreement including but not limited to Generation’s rights with respect to any unpaid aggregate preferred distributions and the related return. As of March 31, 2021, the total unpaid aggregate preferred distributions and related return owed to Generation is $632 million. 

On November 20, 2019, Generation received notice of EDF’s intention to exercise the put option to sell its interest in CENG to Generation, and the put automatically exercised on January 19, 2020 at the end of the sixty-day advance notice period. At this time, Generation cannot reasonably predict the ultimate purchase price that will be paid to EDF for its interest in CENG. The transaction required approval by the FERC and the NYPSC, which approvals were received on July 30, 2020 and April 15, 2021, respectively. The sale process is currently expected to close in the second half of 2021.

Agreement for Sale of Generation’s Solar Business (Exelon and Generation)

On December 8, 2020, Generation entered into an agreement with an affiliate of Brookfield Renewable, for the sale of a significant portion of Generation’s solar business, including 360 MW of generation in operation or under construction across more than 600 sites across the United States. Generation will retain certain solar assets not included in this agreement, primarily Antelope Valley.

Completion of the transaction contemplated by the sale agreement was subject to the satisfaction of several closing conditions which were satisfied in the first quarter of 2021. The sale was completed on March 31, 2021 for a purchase price of $810 million. Generation received cash proceeds of $675 million, net of $125 million long-term debt assumed by the buyer and certain working capital and other post-closing adjustments. Exelon and

56

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 2 — Mergers, Acquisitions, and Dispositions

Generation recognized a pre-tax gain of $68 million which is included in Gain on sales of assets and businesses in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income.

See Note 17 — Debt and Credit Agreements of the Exelon 2020 Form 10-K for additional information on the SolGen nonrecourse debt included as part of the transaction.

Agreement for the Sale of a Generation Biomass Facility (Exelon and Generation)

On April 28, 2021, Generation and ReGenerate Energy Holdings, LLC (“ReGenerate”) entered into a purchase agreement, under which ReGenerate agreed to purchase Generation’s interest in the Albany Green Energy biomass facility. Completion of the transaction is expected in the second half of 2021 and is subject to various customary closing conditions.

As a result, in the second quarter of 2021, Exelon and Generation will reclassify these assets and liabilities as held for sale and expect to record an impairment loss in a range of $135 million to $150 million on a pre-tax basis, which will be recorded within Operating and maintenance expense in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income.

3. Regulatory Matters (All Registrants)

As discussed in Note 3 — Regulatory Matters of the Exelon 2020 Form 10-K, the Registrants are involved in rate and regulatory proceedings at the FERC and their state commissions. The following discusses developments in 2021 and updates to the 2020 Form 10-K.

Utility Regulatory Matters (Exelon, PHI, and the Utility Registrants)

Distribution Base Rate Case Proceedings

The following tables show the completed and pending distribution base rate case proceedings in 2021.

Completed Distribution Base Rate Case Proceedings

Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement (Decrease) Increase		Approved Revenue Requirement (Decrease) Increase		Approved ROE		Approval Date	Rate Effective Date
ComEd - Illinois(a)	April 16, 2020	Electric	$	(11)	$	(14)	8.38	%	December 9, 2020	January 1, 2021
BGE - Maryland(b)	May 15, 2020 (amended September 11, 2020)	Electric	137		81		9.50	%	December 16, 2020	January 1, 2021
		Natural Gas	91		21		9.65	%

__________

(a)ComEd's 2021 approved revenue requirement reflects an increase of $50 million for the initial year revenue requirement for 2021 and a decrease of $64 million related to the annual reconciliation for 2019. The revenue requirement for 2021 and the revenue requirement for 2019 provide for a weighted average debt and equity return on distribution rate base of 6.28%, inclusive of an allowed ROE of 8.38%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points.

(b)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 in 2021, 2022, and 2023, respectively, and natural gas revenue requirement increases of $53 million, $11 million, and $10 million in 2021, 2022, and 2023, respectively. However, the MDPSC utilized certain tax benefits to fully offset the increases in 2021 so that customer rates will remain unchanged from 2020 to 2021. The MDPSC has deferred a decision on whether to use certain tax benefits to offset the revenue requirement increases in 2022 and 2023 and BGE cannot predict the outcome.

57

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 3 — Regulatory Matters

Pending Distribution Base Rate Case Proceedings

Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement Increase		Requested ROE		Expected Approval Timing
ComEd - Illinois(a)	April 16, 2021	Electric	$	51	7.36	%	Fourth quarter of 2021
PECO - Pennsylvania	March 30, 2021	Electric	246		10.95	%	Fourth quarter of 2021
PECO - Pennsylvania	September 30, 2020	Natural Gas	69		10.95	%	Second quarter of 2021
Pepco - District of Columbia(b)	May 30, 2019 (amended June 1, 2020)	Electric	136		9.7	%	Second quarter of 2021
Pepco - Maryland(c)	October 26, 2020 (amended March 31, 2021)	Electric	104		10.2	%	Second quarter of 2021
DPL - Delaware(d)	March 6, 2020 (amended February 2, 2021)	Electric	23		10.3	%	Third quarter of 2021
ACE - New Jersey(e)	December 9, 2020 (amended February 26, 2021)	Electric	67		10.3	%	Fourth quarter of 2021

__________

(a)ComEd's 2022 requested revenue requirement reflects an increase of $40 million for the initial year revenue requirement for 2022 and an increase of $11 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 average monthly 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 average monthly yields for 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points.

(b)Pepco filed the multi-year plan enhanced proposal as an alternative to address the impacts of COVID-19. Reflects a three-year cumulative multi-year plan for 2020 through 2022 and requested revenue requirement increases of $73 million in 2022 and $63 million in 2023, to recover capital investments made during 2018 through 2020 and planned capital investments through the end of 2022.

(c)Reflects a three-year cumulative multi-year plan for April 1, 2021 through March 31, 2024 and total requested revenue requirement increases of $52 million effective April 1, 2023 and $52 million effective April 1, 2024 to recover capital investments made in 2019 and 2020 and planned capital investments through March 31, 2024.

(d)The rates went into effect on October 6, 2020, subject to refund.

(e)Requested increases are before New Jersey sales and use tax. ACE intends to put rates into effect on September 8, 2021 subject to refund.

Transmission Formula Rates

For 2021, the following total increases were included in ComEd’s electric transmission formula rate update. PECO, BGE, Pepco, DPL, and ACE intend to file by the required deadline for the annual update.

Registrant(a)	Initial Revenue Requirement Increase		Annual Reconciliation Increase		Total Revenue Requirement Increase		Allowed Return on Rate Base(b)		Allowed ROE(c)
ComEd	$	33	$	12	$	45	8.20	%	11.50	%

(a)Rates are effective June 30, 2021 - May 31, 2022, subject to review by interested parties pursuant to review protocols of ComEd's tariff.

(b)Represents the weighted average debt and equity return on transmission rate bases.

(c)As part of the FERC-approved settlements of ComEd’s 2007 rate case, the rate of return on common equity is 11.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO, and the common equity component of the ratio used to calculate the weighted average debt and equity return for the transmission formula rate is currently capped at 55%.

58

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, 2020, unless noted below. See Note 3 — Regulatory Matters of the Exelon 2020 Form 10-K for additional information on the specific regulatory assets and liabilities.

ComEd. Regulatory assets increased $106 million primarily due to an increase of $55 million in the Electric Distribution Formula Rate Annual Reconciliations regulatory asset, and $38 million in the Energy Efficiency Costs regulatory asset.

PECO. Regulatory assets increased $56 million primarily due to an increase of $48 million in the Deferred Income Taxes regulatory asset and $9 million in the Vacation Accrual regulatory asset.

BGE. Regulatory liabilities decreased $82 million primarily due to a decrease of $93 million in the Deferred Income Taxes regulatory liability, partially offset by an increase of $9 million in the Electric Energy and Natural Gas Costs regulatory liability.

Capitalized Ratemaking Amounts Not Recognized

The following table presents authorized amounts capitalized for ratemaking purposes related to earnings on shareholders’ investment that are not recognized for financial reporting purposes in Exelon's and the Utility Registrant's 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
March 31, 2021	$	49	$	—	$	—	$	43	$	6	$	3	$	3	$	—
December 31, 2020	51		(1)		—		45		7		4		3		—

_________

(a)Reflects ComEd's unrecognized equity returns/(losses) earned/(incurred) for ratemaking purposes on its electric distribution formula rate regulatory assets.

(b)BGE's authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholders' investment on its AMI programs.

(c)Pepco's and DPL's authorized amounts capitalized for ratemaking purposes relate to earnings on shareholders' investment on their respective AMI Programs and Energy Efficiency and Demand Response Programs. The earnings on energy efficiency are on Pepco DC and DPL DE programs only.

Generation Regulatory Matters (Exelon and Generation)

Impacts of the February 2021 Extreme Cold Weather Event and Texas-based Generating Assets Outages

Beginning on February 15, 2021, Generation’s Texas-based generating assets within the ERCOT market, specifically Colorado Bend II, Wolf Hollow II, and Handley, experienced outages as a result of extreme cold weather conditions. In addition, those weather conditions drove increased demand for service, dramatically increased wholesale power prices, and also increased gas prices in certain regions. In response to the high demand and significantly reduced total generation on the system, the PUCT directed ERCOT to use an administrative price cap of $9,000 per MWh during firm load shedding events.

The estimated impact to Exelon’s and Generation’s Net income for the first quarter of 2021 arising from these market and weather conditions was a reduction of approximately $880 million. The ultimate impact to Exelon’s and Generation’s consolidated financial statements for the full year 2021 may be affected by a number of factors, including final settlement data, the impacts of customer and counterparty credit losses, any state or federal solutions to address the financial challenges caused by the event, and related litigation and contract disputes.

During February and March 2021, various parties with differing interests, including generators and retail providers, filed requests with the PUCT to void the PUCT’s orders setting prices at $9,000 per MWh during firm load shedding events. Other requests were made for the PUCT to enforce its order and reduce prices for 32 hours between February 18 and February 19 after firm load shedding ceased and to cap ancillary services at $9,000 per MWh. Appeals of certain of the PUCT’s orders also have been filed in state court. On April 19, 2021, Generation filed a declaratory action and appeal in state court challenging the PUCT’s orders setting prices at

59

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 3 — Regulatory Matters

$9,000 per MWh. Exelon and Generation cannot predict the outcome of these proceedings or the financial statement impact.

Due to these events, a number of ERCOT market participants experienced bankruptcies, resulting in approximately a $2.9 billion payment shortfall in collections, which is allocated to the remaining ERCOT market participants. Generation recorded its portion of this obligation of approximately $28 million on a discounted basis in the first quarter of 2021, which is to be paid over a term of 96 years. Current ERCOT rules limit recovery of default from market participants to $2.5 million per month market-wide. In February 2021, the PUCT gave ERCOT discretion to disregard its current rules, but ERCOT has declined to exercise that discretion thus far. Generation's request for rehearing of this PUCT order was denied on April 17, 2021 and an appeal is pending in state court. Additionally, several pending legislative proposals were introduced in the Texas legislature during February and March 2021 concerning the amount, timing and allocation of recovery of the $2.9 billion shortfall. Exelon and Generation are monitoring the proposed legislation and cannot predict the outcome or the financial statement impact.

In addition, several other legislative proposals have been introduced in the Texas legislature during February and March 2021 addressing cold-weather preparation for power plants and natural gas production and transportation infrastructure. The proposed legislation provides the PUCT and the Railroad Commission of Texas with the option of imposing fines if the new proposed standards are not met. Exelon and Generation are monitoring the proposed legislation and cannot predict the outcome. However, such proposed legislation could have a material adverse impact in Exelon’s and Generation’s consolidated financial statements.

In February 2021, more than 70 local distribution companies (LDCs) in multiple states throughout the mid-continent region, where Generation serves natural gas transportation customers, issued operational flow orders (OFOs), curtailments or other limitations on natural gas use to preserve adequate pressure on the system. When in effect, gas use above these limitations is severely penalized according to the LDCs’ tariff. Gas supply in many states became restricted due to wells freezing and pipeline compression disruption, while demand was increasing due to the extreme cold temperatures, resulting in extremely high natural gas prices. Due to the extraordinary circumstances, many LDCs and natural gas pipelines are either voluntarily waiving or seeking regulatory approvals to waive the penalties associated with these restrictions. During March 2021, three natural gas pipelines filed individual petitions with the FERC requesting approval to waive these penalties. Generation also filed motions in March 2021 to intervene with the FERC in support of these requests from the pipelines. On March 25, 2021, the FERC issued an order on one of the petitions approving the request to waive the penalties for February 15, 2021. On April 23, 2021, Generation and several other entities filed a request for rehearing and a complaint to expand the order to include additional days of the weather events in February, from February 15 through February 19, 2021. On April 9, 2021 and April 19, 2021, the FERC issued orders on the remaining petitions approving the requests to waive the penalties. Exelon and Generation cannot predict the outcome of the FERC proceeding or the determinations made by the LDCs.

New Jersey Regulatory Matters

New Jersey Clean Energy Legislation. On May 23, 2018, New Jersey enacted legislation that established a ZEC program that provides compensation for nuclear plants that demonstrate to the NJBPU that they meet certain requirements, including that they make a significant contribution to air quality in the state and that their revenues are insufficient to cover their costs and risks. Under the legislation, the NJBPU will issue ZECs to qualifying nuclear power plants and the electric distribution utilities in New Jersey, including ACE, will be required to purchase those ZECs. On April 18, 2019, the NJBPU approved the award of ZECs to Salem 1 and Salem 2. Upon approval, Generation began recognizing revenue for the sale of New Jersey ZECs in the month they are generated. On March 19, 2021, a three-judge panel of the Superior Court of New Jersey Appellate Division unanimously affirmed the NJBPU’s April 2019 order awarding ZECs for the first eligibility period. On April 8, 2021, New Jersey Rate Counsel filed a notice of appeal of the Superior Court’s order to the New Jersey Supreme Court. Exelon and Generation cannot predict the outcome of the appeal. On October 1, 2020, PSEG and Generation filed applications seeking ZECs for the second eligibility period (June 2022 through May 2025). On April 27, 2021, the NJBPU approved the award of ZECs to Salem 1 and Salem 2 for the second eligibility period. See Note 7 — Early Plant Retirements for additional information related to Salem.

New England Regulatory Matters

60

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 3 — Regulatory Matters

Mystic Units 8 & 9 and Everett Marine Terminal Cost of Service Agreement (Exelon and Generation). On March 29, 2018, Generation notified grid operator ISO-NE of its plans to early retire Mystic Units 8 and 9 absent regulatory reforms on June 1, 2022. On May 16, 2018, Generation made a filing with FERC to establish cost-of-service compensation and terms and conditions of service for Mystic Units 8 & 9 for the period between June 1, 2022 - May 31, 2024. On December 20, 2018, FERC issued an order accepting the cost of service compensation, reflecting a number of adjustments to the annual fixed revenue requirement and allowing for recovery of a substantial portion of the costs associated with the adjacent Everett Marine Terminal acquired by Generation in October 2018. Those adjustments were reflected in a compliance filing made on March 1, 2019. In the December 20, 2018 order, FERC also directed a paper hearing on ROE using a new methodology. On January 22, 2019, Exelon and several other parties filed requests for rehearing of certain findings in the order.

On July 17, 2020, FERC issued three orders, which together affirmed the recovery of key elements of Mystic's cost of service compensation, including recovery of costs associated with the operation of the Everett Marine Terminal. FERC directed a downward adjustment to the rate base for Mystic Units 8 and 9, the effect of which will be partially offset by elimination of a crediting mechanism for third party gas sales during the term of the cost of service agreement. In addition, several parties filed protests to a compliance filing by Generation on September 15, 2020, taking issue with how gross plant in-service was calculated, and Generation filed an answer to the protests on October 21, 2020. On December 21, 2020, FERC issued an order on rehearing of the three July 17, 2020 orders, clarifying several cost of service provisions. Several parties appealed the December 21, 2020 order to the U.S. Court of Appeals for the D.C. Circuit and that appeal was consolidated with appeals of orders issued December 20, 2018 and July 17, 2020 in the Mystic proceeding. The briefing schedule for the consolidated appeal has not yet been set.

On February 25, 2021, Mystic made its filing to comply with the December 21, 2020 order. On April 26, 2021, FERC rejected Mystic’s language and directed another compliance filing relating to the claw back provision language, which only applies if Mystic 8 and 9 were to continue operation after the conclusion of the cost-of-service period. FERC’s April 26, 2021 order also accepted in part and rejected in part Mystic’s September 15, 2020 compliance filing. It directed a further compliance filing in 60 days consistent with the information provided in Mystic’s October 21, 2020 answer to protests.

On August 25, 2020, a group of New England generators filed a complaint against Generation seeking to extend the scope of the claw back provision in the cost-of-service agreement, whereby Generation would refund certain amounts recovered during the term of the cost of service if it returns to market afterwards. On April 15, 2021 FERC dismissed the complaint.

On February 16, 2021, Generation filed an unopposed motion to voluntarily dismiss an appeal filed with the U.S. Court of Appeals for the D.C. Circuit stemming from a June 2020 complaint filed with the FERC against ISO-NE over failures to follow its tariff in evaluating Mystic for transmission security for the 2024 to 2025 Capacity Commitment Period, which was granted on February 18, 2021.

See Note 7 — Early Plant Retirements for additional information on the impacts of Generation’s August 2020 decision to retire Mystic Units 8 & 9 upon expiration of the cost of service agreement.

Federal Regulatory Matters

Operating License Renewals

Conowingo Hydroelectric Project. On August 29, 2012, Generation submitted a hydroelectric license application to FERC for a new license for the Conowingo Hydroelectric Project (Conowingo). In connection with Generation’s efforts to obtain a water quality certification pursuant to Section 401 of the Clean Water Act (401 Certification) from MDE for Conowingo, Generation had been working with MDE and other stakeholders to resolve water quality licensing issues, including: (1) water quality, (2) fish habitat, and (3) sediment.

On April 27, 2018, MDE issued its 401 Certification for Conowingo. On October 29, 2019, Generation and MDE filed with FERC a Joint Offer of Settlement (Offer of Settlement) that would resolve all outstanding issues relating to the 401 Certification. Pursuant to the Offer of Settlement, the parties submitted Proposed License Articles to FERC to be incorporated by FERC into the new license in accordance with FERC’s discretionary authority under the Federal Power Act.

61

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 3 — Regulatory Matters

On March 19, 2021, FERC issued a new 50-year license for Conowingo, effective March 1, 2021. FERC adopted the Proposed License Articles into the new license only making modifications it deemed necessary to allow FERC to enforce the Proposed License Articles. Consistent with the Offer of Settlement, FERC found that MDE waived its 401 Certification.

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. Generation’s primary sources of revenue include competitive sales of power, natural gas, and other energy-related products and services. The Utility Registrants’ primary sources of revenue include regulated electric and gas tariff sales, distribution, and transmission services.

See Note 4 — Revenue from Contracts with Customers of the Exelon 2020 Form 10-K for additional information regarding the primary sources of revenue for the Registrants.

Contract Balances (All Registrants)

Contract Assets

Generation records contract assets for the revenue recognized on the construction and installation of energy efficiency assets and new power generating facilities before Generation has an unconditional right to bill for and receive the consideration from the customer. These contract assets are subsequently reclassified to receivables when the right to payment becomes unconditional. Generation records contract assets and contract receivables within Other current assets and Customer accounts receivable, net, respectively, within Exelon’s and Generation’s Consolidated Balance Sheets.

The following table provides a rollforward of the contract assets reflected in Exelon's and Generation's Consolidated Balance Sheets for the three months ended March 31, 2021 and 2020. The Utility Registrants do not have any contract assets.

	Exelon		Generation
Balance as of December 31, 2020	$	144	$	144
Amounts reclassified to receivables	(16)		(16)
Revenues recognized	13		13
Amounts previously held-for-sale	12		12
Balance as of March 31, 2021	$	153	$	153
	Exelon		Generation
Balance as of December 31, 2019	$	174	$	174
Amounts reclassified to receivables	(19)		(19)
Revenues recognized	17		17
Balance as of March 31, 2020	$	172	$	172

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 within Other current liabilities and Other noncurrent liabilities within the Registrants' Consolidated Balance Sheets.

For Generation, these contract liabilities primarily relate to upfront consideration received or due for equipment service plans, and the Illinois ZEC program that introduces a cap on the total consideration to be received by Generation.

62

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 4 — Revenue from Contracts with Customers

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, Generation's, PHI's, Pepco's, DPL's, and ACE's Consolidated Balance Sheets for the three months ended March 31, 2021 and 2020. As of March 31, 2021 and December 31, 2020, ComEd's, PECO's, and BGE's contract liabilities were immaterial.

	Exelon		Generation		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	151	$	84	$	118	$	94	$	12	$	12
Consideration received or due	20		31		—		—		—		—
Revenues recognized	(27)		(64)		(2)		(2)		—		—
Amounts previously held-for-sale	3		3		—		—		—		—
Balance as of March 31, 2021	$	147	$	54	$	116	$	92	$	12	$	12
	Exelon		Generation		PHI		Pepco		DPL		ACE
Balance as of December 31, 2019	$	33	$	71	$	—	$	—	$	—	$	—
Consideration received or due	20		55		—		—		—		—
Revenues recognized	(24)		(70)		—		—		—		—
Balance as of March 31, 2020	$	29	$	56	$	—	$	—	$	—	$	—

The following table reflects revenues recognized in the three months ended March 31, 2021 and 2020, which were included in contract liabilities at December 31, 2020 and 2019, respectively:

	Three Months Ended March 31,
	2021		2020
Exelon	$	17	$	9
Generation	39		19
PHI	2		—
Pepco	2		—

Transaction Price Allocated to Remaining Performance Obligations (All Registrants)

The following table shows the amounts of future revenues expected to be recorded in each year for performance obligations that are unsatisfied or partially unsatisfied as of March 31, 2021. 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 Generation's power and gas sales contracts as they contain variable volumes and/or variable pricing. This disclosure also 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.

	2021		2022		2023		2024		2025 and thereafter		Total
Exelon	$	233	$	100	$	56	$	41	$	330	$	760
Generation	286		131		56		35		243		751
PHI	7		8		8		6		87		116
Pepco	5		6		6		5		70		92
DPL	1		1		1		—		9		12
ACE	1		1		1		1		8		12

63

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 4 — Revenue from Contracts with Customers

Revenue Disaggregation (All Registrants)

The Registrants disaggregate revenue recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. See Note 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 CODM in deciding how to evaluate performance and allocate resources at each of the Registrants.

Exelon has eleven reportable segments, which include Generation's five reportable segments consisting of the Mid-Atlantic, Midwest, New York, ERCOT, and all other power regions referred to collectively as “Other Power Regions” and ComEd, PECO, BGE, and PHI's three reportable segments consisting of Pepco, DPL, and ACE. ComEd, PECO, BGE, Pepco, DPL, and ACE each represent a single reportable segment, and as such, no separate segment information is provided for these Registrants. Exelon, ComEd, PECO, BGE, Pepco, DPL, and ACE's CODMs evaluate the performance of and allocate resources to ComEd, PECO, BGE, Pepco, DPL, and ACE based on net income.

The basis for Generation's reportable segments is the integrated management of its electricity business that is located in different geographic regions, and largely representative of the footprints of ISO/RTO and/or NERC regions, which utilize multiple supply sources to provide electricity through various distribution channels (wholesale and retail). Generation's hedging strategies and risk metrics are also aligned to these same geographic regions. Descriptions of each of Generation’s five reportable segments are as follows:

•Mid-Atlantic represents operations in the eastern half of PJM, which includes New Jersey, Maryland, Virginia, West Virginia, Delaware, the District of Columbia, and parts of Pennsylvania and North Carolina.

•Midwest represents operations in the western half of PJM and the United States footprint of MISO, excluding MISO’s Southern Region.

•New York represents operations within NYISO.

•ERCOT represents operations within Electric Reliability Council of Texas.

•Other Power Regions:

•New England represents the operations within ISO-NE.

•South represents operations in the FRCC, MISO’s Southern Region, and the remaining portions of the SERC not included within MISO or PJM.

•West represents operations in the WECC, which includes California ISO.

•Canada represents operations across the entire country of Canada and includes AESO, OIESO, and the Canadian portion of MISO.

The CODMs for Exelon and Generation evaluate the performance of Generation’s electric business activities and allocate resources based on RNF. Generation believes that RNF is a useful measurement of operational performance. RNF is not a presentation defined under GAAP and may not be comparable to other companies’ presentations or deemed more useful than the GAAP information provided elsewhere in this report. Generation’s operating revenues include all sales to third parties and affiliated sales to the Utility Registrants. Purchased power costs include all costs associated with the procurement and supply of electricity including capacity, energy, and ancillary services. Fuel expense includes the fuel costs for Generation’s owned generation and fuel costs associated with tolling agreements. The results of Generation's other business activities are not regularly reviewed by the CODM and are therefore not classified as operating segments or included in the regional reportable segment amounts. These activities include natural gas, as well as other miscellaneous business activities that are not significant to Generation's overall operating revenues or results of operations. Further,

64

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 5 — Segment Information

Generation’s unrealized mark-to-market gains and losses on economic hedging activities and its amortization of certain intangible assets and liabilities relating to commodity contracts recorded at fair value from mergers and acquisitions are also excluded from the regional reportable segment amounts. Exelon and Generation do not use a measure of total assets in making decisions regarding allocating resources to or assessing the performance of these reportable segments.

An analysis and reconciliation of the Registrants’ reportable segment information to the respective information in the consolidated financial statements for the three months ended March 31, 2021 and 2020 is as follows:

Three Months Ended March 31, 2021 and 2020

	Generation		ComEd		PECO		BGE		PHI		Other(a)		Intersegment Eliminations		Exelon
Operating revenues(b):
2021
Competitive businesses electric revenues	$	4,187	$	—	$	—	$	—	$	—	$	—	$	(293)	$	3,894
Competitive businesses natural gas revenues	1,326		—		—		—		—		—				1,326
Competitive businesses other revenues	46		—		—		—		—		—		(1)		45
Rate-regulated electric revenues	—		1,535		661		632		1,170		—		(10)		3,988
Rate-regulated natural gas revenues	—		—		228		342		71		—		(4)		637
Shared service and other revenues	—		—		—		—		3		491		(494)		—
Total operating revenues	$	5,559	$	1,535	$	889	$	974	$	1,244	$	491	$	(802)	$	9,890
2020
Competitive businesses electric revenues	$	3,752	$	—	$	—	$	—	$	—	$	—	$	(326)	$	3,426
Competitive businesses natural gas revenues	672		—		—		—		—		—		(3)		669
Competitive businesses other revenues	309		—		—		—		—		—		(1)		308
Rate-regulated electric revenues	—		1,439		604		613		1,104		—		(12)		3,748
Rate-regulated natural gas revenues	—		—		209		324		64		—		(2)		595
Shared service and other revenues	—		—		—		—		3		480		(482)		1
Total operating revenues	$	4,733	$	1,439	$	813	$	937	$	1,171	$	480	$	(826)	$	8,747
Intersegment revenues(c):
2021	$	295	$	6	$	2	$	6	$	3	$	487	$	(799)	$	—
2020	330		5		2		6		3		479		(824)		1
Depreciation and amortization:

65

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 5 — Segment Information

	Generation		ComEd		PECO		BGE		PHI		Other(a)		Intersegment Eliminations		Exelon
2021	$	940	$	292	$	86	$	152	$	210	$	17	$	—	$	1,697
2020	304		273		86		143		194		21		—		1,021
Operating expenses:
2021	$	6,672	$	1,210	$	679	$	752	$	1,058	$	492	$	(781)	$	10,082
2020	4,400		1,151		625		688		1,000		481		(816)		7,529
Interest expense, net:
2021	$	72	$	96	$	38	$	34	$	67	$	79	$	—	$	386
2020	109		94		36		32		67		72		—		410
Income (loss) before income taxes:
2021	$	(947)	$	236	$	177	$	196	$	136	$	(80)	$	—	$	(282)
2020	(547)		204		155		222		119		(69)		1		85
Income Taxes:
2021	$	(179)	$	39	$	10	$	(13)	$	8	$	116	$	—	$	(19)
2020	(389)		36		15		41		11		(8)		—		(294)
Net income (loss):
2021	$	(769)	$	197	$	167	$	209	$	128	$	(196)	$	—	$	(264)
2020	(161)		168		140		181		108		(61)		1		376
Capital Expenditures:
2021	$	382	$	613	$	295	$	336	$	456	$	58	$	—	$	2,140
2020	558		506		259		283		376		34		—		2,016
Total assets:
March 31, 2021	$	47,326	$	34,825	$	12,937	$	11,759	$	24,387	$	8,788	$	(10,022)	$	130,000
December 31, 2020	48,094		34,466		12,531		11,650		23,736		9,005		(10,165)		129,317

__________

(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 17 — Supplemental Financial Information for additional information on total utility taxes.

(c)Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory accounting guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. See Note 18 — Related Party Transactions for additional information on intersegment revenues.

66

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):
2021
Rate-regulated electric revenues	$	553	$	311	$	310	$	—	$	(4)	$	1,170
Rate-regulated natural gas revenues	—		71		—		—		—		71
Shared service and other revenues	—		—		—		95		(92)		3
Total operating revenues	$	553	$	382	$	310	$	95	$	(96)	$	1,244
2020
Rate-regulated electric revenues	$	544	$	286	$	276	$	—	$	(2)	$	1,104
Rate-regulated natural gas revenues	—		64		—		—		—		64
Shared service and other revenues	—		—		—		93		(90)		3
Total operating revenues	$	544	$	350	$	276	$	93	$	(92)	$	1,171
Intersegment revenues(c):
2021	$	1	$	2	$	1	$	95	$	(96)	$	3
2020	1		2		1		92		(93)		3
Depreciation and amortization:
2021	$	102	$	53	$	47	$	8	$	—	$	210
2020	95		48		43		9		(1)		194
Operating expenses:
2021	$	466	$	309	$	282	$	97	$	(96)	$	1,058
2020	462		284		251		93		(90)		1,000
Interest expense, net:
2021	$	34	$	15	$	15	$	3	$	—	$	67
2020	34		16		15		3		(1)		67
Income (loss) before income taxes:
2021	$	65	$	61	$	14	$	(4)	$	—	$	136
2020(d)	57		52		14		(4)		—		119
Income Taxes:
2021	$	6	$	5	$	—	$	(3)	$	—	$	8
2020	5		7		1		(2)		—		11
Net income (loss):
2021	$	59	$	56	$	14	$	(1)	$	—	$	128
2020	52		45		13		(2)		—		108
Capital Expenditures:
2021	$	220	$	112	$	123	$	1	$	—	$	456
2020	180		95		101		—		—		376
Total assets:
March 31, 2021	$	9,493	$	5,232	$	4,679	$	5,020	$	(37)	$	24,387
December 31, 2020	9,264		5,140		4,286		5,079		(33)		23,736

__________

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

(b)Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 17 — Supplemental Financial Information for additional information on total utility taxes.

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

(d)The Income (loss) before income taxes in Other and Intersegment Eliminations have been adjusted by an offsetting $110 million in 2020.

The following tables disaggregate the Registrants' revenue recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. For Generation, the disaggregation of revenues reflects Generation’s two primary products of

67

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 5 — Segment Information

power sales and natural gas sales, with further disaggregation of power sales provided by geographic region. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of rate-regulated electric sales and rate-regulated natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon’s disaggregated revenues are consistent with Generation and the Utility Registrants, but exclude any intercompany revenues.

Competitive Business Revenues (Generation):

	Three Months Ended March 31, 2021
	Revenues from external customers(a)						Intersegment Revenues		Total Revenues
	Contracts with customers		Other(b)		Total
Mid-Atlantic	$	1,174	$	(14)	$	1,160	$	5	$	1,165
Midwest	1,009		(11)		998		—		998
New York	382		(45)		337		—		337
ERCOT	353		(101)		252		5		257
Other Power Regions	1,172		268		1,440		(10)		1,430
Total Competitive Businesses Electric Revenues	4,090		97		4,187		—		4,187
Competitive Businesses Natural Gas Revenues	864		462		1,326		—		1,326
Competitive Businesses Other Revenues(c)	89		(43)		46		—		46
Total Generation Consolidated Operating Revenues	$	5,043	$	516	$	5,559	$	—	$	5,559

	Three Months Ended March 31, 2020
	Revenues from external customers(a)						Intersegment revenues		Total Revenues
	Contracts with customers		Other(b)		Total
Mid-Atlantic	$	1,264	$	(96)	$	1,168	$	6	$	1,174
Midwest	944		64		1,008		(6)		1,002
New York	335		(21)		314		—		314
ERCOT	155		28		183		7		190
Other Power Regions	1,007		72		1,079		(7)		1,072
Total Competitive Businesses Electric Revenues	3,705		47		3,752		—		3,752
Competitive Businesses Natural Gas Revenues	503		169		672		—		672
Competitive Businesses Other Revenues(c)	99		210		309		—		309
Total Generation Consolidated Operating Revenues	$	4,307	$	426	$	4,733	$	—	$	4,733

__________

(a)Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants.

(b)Includes revenues from derivatives and leases.

(c)Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market losses of $84 million and gains of $179 million in 2021 and 2020, respectively, and elimination of intersegment revenues.

68

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 5 — Segment Information

Revenues net of purchased power and fuel expense (Generation):

	Three Months Ended March 31, 2021						Three Months Ended March 31, 2020
	RNF from external customers(a)		Intersegment RNF		Total RNF		RNF from external customers(a)		Intersegment RNF		Total RNF
Mid-Atlantic	$	562	$	5	$	567	$	559	$	8	$	567
Midwest	702		—		702		732		(5)		727
New York	240		2		242		189		4		193
ERCOT	(1,036)		(148)		(1,184)		76		4		80
Other Power Regions	250		(33)		217		177		(19)		158
Total Revenues net of purchased power and fuel expense for Reportable Segments	718		(174)		544		1,733		(8)		1,725
Other(b)	231		174		405		296		8		304
Total Generation Revenues net of purchased power and fuel expense	$	949	$	—	$	949	$	2,029	$	—	$	2,029

__________

(a)Includes purchases and sales from/to third parties and affiliated sales to the Utility Registrants.

(b)Other represents activities not allocated to a region. See text above for a description of included activities. Primarily includes:

•unrealized mark-to-market gains of $175 million and gains of $132 million in 2021 and 2020, respectively;

•accelerated nuclear fuel amortization associated with announced early plant retirements as discussed in Note 7 - Early Plant Retirements of $54 million in 2021; and

• the elimination of intersegment RNF.

69

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 5 — Segment Information

Electric and Gas Revenue by Customer Class (Utility Registrants):

	Three Months Ended March 31, 2021
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Rate-regulated electric revenues
Residential	$	741	$	433	$	362	$	605	$	253	$	190	$	162
Small commercial & industrial	367		100		69		118		33		46		39
Large commercial & industrial	134		57		105		248		184		21		43
Public authorities & electric railroads	11		9		7		13		6		4		3
Other(a)	220		52		77		143		51		41		52
Total rate-regulated electric revenues(b)	$	1,473	$	651	$	620	$	1,127	$	527	$	302	$	299
Rate-regulated natural gas revenues
Residential	$	—	$	160	$	216	$	46	$	—	$	46	$	—
Small commercial & industrial	—		59		35		18		—		18		—
Large commercial & industrial	—		—		54		2		—		2		—
Transportation	—		7		—		4		—		4		—
Other(c)	—		2		31		1		—		1		—
Total rate-regulated natural gas revenues(d)	$	—	$	228	$	336	$	71	$	—	$	71	$	—
Total rate-regulated revenues from contracts with customers	$	1,473	$	879	$	956	$	1,198	$	527	$	373	$	299
Other revenues
Revenues from alternative revenue programs	$	54	$	10	$	18	$	46	$	26	$	9	$	11
Other rate-regulated electric revenues(e)	8		—		—		—		—		—		—
Other rate-regulated natural gas revenues(e)	—		—		—		—		—		—		—
Total other revenues	$	62	$	10	$	18	$	46	$	26	$	9	$	11
Total rate-regulated revenues for reportable segments	$	1,535	$	889	$	974	$	1,244	$	553	$	382	$	310

70

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 5 — Segment Information

	Three Months Ended March 31, 2020
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Rate-regulated electric revenues
Residential	$	701	$	382	$	339	$	534	$	236	$	161	$	137
Small commercial & industrial	362		99		67		115		35		43		37
Large commercial & industrial	134		53		103		253		188		23		42
Public authorities & electric railroads	13		7		7		15		9		3		3
Other(a)	211		58		79		169		60		54		55
Total rate-regulated electric revenues(b)	$	1,421	$	599	$	595	$	1,086	$	528	$	284	$	274
Rate-regulated natural gas revenues
Residential	$	—	$	150	$	206	$	40	$	—	$	40	$	—
Small commercial & industrial	—		51		34		17		—		17		—
Large commercial & industrial	—		—		51		1		—		1		—
Transportation	—		6		—		4		—		4		—
Other(c)	—		1		9		2		—		2		—
Total rate-regulated natural gas revenues(d)	$	—	$	208	$	300	$	64	$	—	$	64	$	—
Total rate-regulated revenues from contracts with customers	$	1,421	$	807	$	895	$	1,150	$	528	$	348	$	274
Other revenues
Revenues from alternative revenue programs	$	12	$	2	$	36	$	18	$	15	$	1	$	1
Other rate-regulated electric revenues(e)	6		3		3		3		1		1		1
Other rate-regulated natural gas revenues(e)	—		1		3		—		—		—		—
Total other revenues	$	18	$	6	$	42	$	21	$	16	$	2	$	2
Total rate-regulated revenues for reportable segments	$	1,439	$	813	$	937	$	1,171	$	544	$	350	$	276

__________

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

(b)Includes operating revenues from affiliates in 2021 and 2020 respectively of:

•$6 million, $5 million at ComEd

•$1 million, $2 million at PECO

•$2 million, $6 million at BGE

•$3 million, $3 million at PHI

•$1 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 2021 and 2020 respectively of:

•less than $1 million at PECO for both 2021 and 2020

•$4 million, $3 million at BGE

(e)Includes late payment charge revenues.

71

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 (All Registrants)

The following tables present the rollforward of Allowance for Credit Losses on Customer Accounts Receivable.

	Three Months Ended March 31, 2021
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	366	$	32	$	97	$	116	$	35	$	86	$	32	$	22	$	32
Plus: Current period provision for expected credit losses(a)	104		34		21		20		9		20		11		6		3
Less: Write-offs, net of recoveries(b)	28		1		15		6		1		5		2		3		—
Balance as of March 31, 2021	$	442	$	65	$	103	$	130	$	43	$	101	$	41	$	25	$	35
	Three Months Ended March 31, 2020
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2019	$	243	$	80	$	59	$	55	$	12	$	37	$	13	$	11	$	13
Plus: Current period provision for expected credit losses	55		4		18		18		8		7		3		2		2
Less: Write-offs, net of recoveries(b)	20		3		6		7		2		2		1		—		1
Balance as of March 31, 2020	$	278	$	81	$	71	$	66	$	18	$	42	$	15	$	13	$	14

_________

(a)For Generation, primarily relates to the impacts of the February 2021 extreme cold weather event. See Note 3 — Regulatory Matters for additional information. For the Utility Registrants, the increase is primarily as a result of increased receivable balances due to the colder weather and the increased aging of receivables, the temporary suspension of customer disconnections for non-payment, temporary cessation of new late payment fees, and reconnection of service to customers previously disconnected due to COVID-19.

(b)Recoveries were not material to the Registrants.

72

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 March 31, 2021
	Exelon		Generation		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 for expected credit losses	10		—		1		4		1		4		2		1		1
Less: Write-offs, net of recoveries(a)	2		—		—		1		1		—		—		—		—
Balance as of March 31, 2021	$	79	$	—	$	22	$	11	$	9	$	37	$	15	$	10	$	12
	Three Months Ended March 31, 2020
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2019	$	48	$	—	$	20	$	7	$	5	$	16	$	7	$	4	$	5
Plus: Current period provision for expected credit losses	8		—		3		1		2		2		1		—		1
Less: Write-offs, net of recoveries(a)	4		—		1		1		2		—		—		—		—
Balance as of March 31, 2020	$	52	$	—	$	22	$	7	$	5	$	18	$	8	$	4	$	6

_________

(a)Recoveries were not material to the Registrants.

Unbilled Customer Revenue (All Registrants)

The following table provides additional information about unbilled customer revenues recorded in the Registrants' Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020.

	Unbilled customer revenues(a)
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2021	$	1,178	$	671	$	161	$	102	$	126	$	118	$	58	$	38	$	22
December 31, 2020	998		258		218		147		197		178		87		62		29

_________

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

Sales of Customer Accounts Receivable (Exelon and Generation)

On April 8, 2020, NER, a bankruptcy remote, special purpose entity, which is wholly-owned by Generation, entered into a revolving accounts receivable financing arrangement with a number of financial institutions and a commercial paper conduit (the Purchasers) to sell certain customer accounts receivable (the Facility). The Facility had a maximum funding limit of $750 million and was scheduled to expire on April 7, 2021, unless renewed by the mutual consent of the parties in accordance with its terms. The Facility was renewed on March 29, 2021. The Facility term was extended through March 29, 2024, unless further renewed by the mutual consent of the parties, and the maximum funding limit was increased to $900 million. Under the Facility, NER may sell eligible short-term customer accounts receivable to the Purchasers in exchange for cash and subordinated interest. The transfers are reported as sales of receivables in Exelon’s and Generation’s consolidated financial statements. The subordinated interest in collections upon the receivables sold to the Purchasers is referred to as the DPP, which is reflected in Other current assets on Exelon’s and Generation’s Consolidated Balance Sheets.

73

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 6 — Accounts Receivable

On April 8, 2020, Generation derecognized and transferred approximately $1.2 billion of receivables at fair value to the Purchasers in exchange for approximately $500 million in cash purchase price and $650 million of DPP.

On February 17, 2021, Generation received additional cash of $250 million from the Purchasers for the remaining available funding in the Facility.

On March 31, 2021, Generation received cash of approximately $150 million from the Purchasers in connection with the increased funding limit at the time of the Facility renewal.

The following table summarizes the impact of the sale of certain receivables:

	March 31, 2021		December 31, 2020
Derecognized receivables transferred at fair value	$	1,301	$	1,139
Cash proceeds received	900		500
DPP	401		639

	Three Months Ended March 31, 2021
Loss on sale of receivables(a)	$	17

_________

(a)Reflected in Operating and maintenance expense on Exelon's and Generation's Consolidated Statement of Operations and Comprehensive Income.

	Three Months Ended March 31, 2021
Proceeds from new transfers(a)	$	1,036
Cash collections received on DPP and reinvested in the Facility(b)	1,174
Cash collections reinvested in the Facility	2,210

_________

(a)Customer accounts receivable sold into the Facility were $2,375 million for the three months ended March 31, 2021.

(b)Does not include the $400 million in cash proceeds received from the Purchasers in the first quarter of 2021.

Generation’s risk of loss following the transfer of accounts receivable is limited to the DPP outstanding.  Payment of DPP is not subject to significant risks other than delinquencies and credit losses on accounts receivable transferred, which have historically been and are expected to be immaterial. Generation continues to service the receivables sold in exchange for a servicing fee. Generation did not record a servicing asset or liability as the servicing fees were immaterial.

Generation recognizes the cash proceeds received upon sale in Net cash provided by operating activities in the Consolidated Statement of Cash Flows. The collection and reinvestment of DPP is recognized in Net cash provided by investing activities of the Consolidated Statement of Cash Flows.

See Note 13 — Fair Value of Financial Assets and Liabilities and Note 16 — Variable Interest Entities for additional information.

Other Purchases and Sales of Customer and Other Accounts Receivables (All Registrants)

Generation is required, under supplier tariffs in ISO-NE, MISO, NYISO, and PJM, to sell customer and other receivables to utility companies, which include the Utility Registrants. The Utility Registrants are required, under separate legislation and regulations in Illinois, Pennsylvania, Maryland, District of Columbia, and New Jersey, to purchase certain receivables from alternative retail electric and, as applicable, natural gas suppliers that participate in the utilities' consolidated billing. The following tables present the total receivables purchased and sold.

74

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 6 — Accounts Receivable

	Three Months Ended March 31, 2021
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Total receivables purchased	$	1,011	$	—	$	266	$	290	$	199	$	268	$	166	$	56	$	46
Total receivables sold	69		81		—		—		—		—		—		—		—
Related party transactions:
Receivables purchased from Generation	—		—		—		—		12		—		—		—		—
Receivables sold to the Utility Registrants	—		12		—		—		—		—		—		—		—

	Three Months Ended March 31, 2020
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Total receivables purchased	$	781	$	—	$	280	$	284	$	195	$	264	$	165	$	53	$	46
Total receivables sold	507		749		—		—		—		—		—		—		—
Related party transactions:
Receivables purchased from Generation	—		—		34		67		69		72		51		13		8
Receivables sold to the Utility Registrants	—		242		—		—		—		—		—		—		—

7. Early Plant Retirements (Exelon and Generation)

Exelon and Generation continuously evaluate factors that affect the current and expected economic value of Generation’s plants, including, but not limited to: market power prices, results of capacity auctions, potential legislative and regulatory solutions to ensure plants are fairly compensated for benefits they provide through their carbon-free emissions, reliability, or fuel security, and the impact of potential rules from the EPA requiring reduction of carbon and other emissions and the efforts of states to implement those final rules. The precise timing of an early retirement date for any plant, and the resulting financial statement impacts, may be affected by many factors, including the status of potential regulatory or legislative solutions, results of any transmission system reliability study assessments, the nature of any co-owner requirements and stipulations, and NDT fund requirements for nuclear plants, among other factors. However, the earliest retirement date for any plant would usually be the first year in which the unit does not have capacity or other obligations, and where applicable, just prior to its next scheduled nuclear refueling outage.

Nuclear Generation

In 2015 and 2016, Generation identified the Clinton and Quad Cities nuclear plants in Illinois, Ginna and Nine Mile Point nuclear plants in New York, and TMI nuclear plant in Pennsylvania as having the greatest risk of early retirement based on economic valuation and other factors. In 2017, PSEG made public similar financial challenges facing its New Jersey nuclear plants, including Salem, of which Generation owns a 42.59% ownership interest. PSEG is the operator of Salem and also has the decision-making authority to retire Salem.

Assuming the continued effectiveness of the Illinois ZES, New Jersey ZEC program, and the New York CES, Generation and CENG, through its ownership of Ginna and Nine Mile Point, no longer consider Clinton, Quad Cities, Salem, Ginna, or Nine Mile Point to be at heightened risk for early retirement. However, to the extent the Illinois ZES, New Jersey ZEC program, or the New York CES do not operate as expected over their full terms, each of these plants, in addition to FitzPatrick, would be at heightened risk for early retirement, which could have a material impact on Exelon’s and Generation’s future financial statements. In addition, FERC’s December 19, 2019 order on the MOPR in PJM may undermine the continued effectiveness of the Illinois ZES and the New

75

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 7 — Early Plant Retirements

Jersey ZEC program unless Illinois and New Jersey implement an FRR mechanism under which the Generation plants in these states would be removed from PJM’s capacity auction. See Note 3 — Regulatory Matters for additional information on the New Jersey ZEC program and Note 3 — Regulatory Matters of the 2020 Form 10-K for additional information on the Illinois ZES, New York CES, and FERC's December 19, 2019 order on the MOPR in PJM.

Generation’s Dresden, Byron, and Braidwood nuclear plants in Illinois are also showing increased signs of economic distress, in a market that does not currently compensate them for their unique contribution to grid resiliency and their ability to produce large amounts of energy without carbon and air pollution. The May 2018 PJM capacity auction for the 2021-2022 planning year resulted in the largest volume of nuclear capacity ever not selected in the auction, including all of Dresden, and portions of Byron and Braidwood. While all of LaSalle's capacity did clear in the 2021-2022 planning year auction, Generation has become increasingly concerned about the economic viability of this plant as well in a landscape where energy market prices remain depressed and energy market rules remain fatally flawed.

On August 27, 2020, Generation announced that it intends to permanently cease generation operations at Byron in September 2021 and at Dresden in November 2021. The current NRC licenses for Byron Units 1 and 2 expire in 2044 and 2046, respectively, and the licenses for Dresden Units 2 and 3 expire in 2029 and 2031, respectively.

As a result of the decision to early retire Byron and Dresden, Exelon and Generation recognized certain one-time charges in the third and fourth quarters of 2020 related to materials and supplies inventory reserve adjustments, employee-related costs including severance benefit costs further discussed below, and construction work-in-progress impairments, among other items. In addition, as a result of the decisions to early retire Byron and Dresden, there are ongoing annual financial impacts stemming from shortening the expected economic useful lives of these nuclear plants primarily related to accelerated depreciation of plant assets (including any ARC), accelerated amortization of nuclear fuel, and changes in ARO accretion expense associated with the changes in decommissioning timing and cost assumptions to reflect an earlier retirement date. The total impact for the three months ended March 31, 2021 on Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income is summarized in the table below.

Income statement expense (pre-tax)	Three Months Ended March 31, 2021(a)
Depreciation and amortization
Accelerated depreciation(a)	$	620
Accelerated nuclear fuel amortization	54
Operating and maintenance
Other charges	2
Contractual offset(b)	(226)
Total	$	450

_________

(a)Includes the accelerated depreciation of plant assets including any ARC.

(b)Reflects contractual offset for ARO accretion and ARC depreciation. Based on the regulatory agreement with the ICC, decommissioning-related activities in the first quarter of 2021 have been offset within Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. The offset in 2021 resulted in an equal adjustment to the noncurrent payables to ComEd at Generation and an adjustment to the regulatory liabilities at ComEd. See Note 10 - Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information.

76

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 7 — Early Plant Retirements

Severance benefit costs will be provided to employees impacted by the early retirements of Byron and Dresden, to the extent they are not redeployed to other nuclear plants. In 2020, Exelon and Generation recorded estimated severance expense of $81 million within Operating and maintenance expense in their Consolidated Statements of Operations and Comprehensive Income. The severance liability was $81 million as of March 31, 2021 on Exelon's and Generation's Consolidated Balance Sheets. The final amount of severance benefit costs will depend on the specific employees severed.

The following table provides the balance sheet amounts as of March 31, 2021 for Exelon's and Generation's significant assets and liabilities associated with the Braidwood and LaSalle nuclear plants. Current depreciation provisions are based on the estimated useful lives of these nuclear generating stations, which reflect the first renewal of the operating licenses.

	Braidwood		LaSalle		Total
Asset Balances
Materials and supplies inventory, net	$	83	$	103	$	186
Nuclear fuel inventory, net	165		264		429
Completed plant, net	1,379		1,566		2,945
Construction work in progress	33		70		103
Liability Balances
Asset retirement obligation	(577)		(964)		(1,541)
NRC License First Renewal Term	2046 (Unit 1)		2042 (Unit 1)
	2047 (Unit 2)		2043 (Unit 2)

Exelon continues to work with stakeholders on state policy solutions, while also advocating for broader market reforms at the regional and federal level. The absence of such solutions or reforms could result in future impairments of the Midwest asset group, or accelerated depreciation for specific plants over their shortened estimated useful lives, both of which could have a material unfavorable impact on Exelon's and Generation's future results of operations.

Other Generation

In March 2018, Generation notified ISO-NE of its plans to early retire, among other assets, the Mystic Generating Station's units 8 and 9 (Mystic 8 and 9) absent regulatory reforms to properly value reliability and regional fuel security. Thereafter, ISO-NE identified Mystic 8 and 9 as being needed to ensure fuel security for the region and entered into a cost of service agreement with these two units for the period between June 1, 2022 - May 31, 2024. The agreement was approved by the FERC in December 2018.

On June 10, 2020, Generation filed a complaint with FERC against ISO-NE stating that ISO-NE failed to follow its tariff with respect to its evaluation of Mystic 8 and 9 for transmission security for the 2024 to 2025 Capacity Commitment Period and that the modifications that ISO-NE made to its unfiled planning procedures to avoid retaining Mystic 8 and 9 should have been filed with FERC for approval. On August 17, 2020, FERC issued an order denying the complaint. As a result, on August 20, 2020, Exelon determined that Generation will permanently cease generation operations at Mystic 8 and 9 at the expiration of the cost of service commitment in May 2024. See Note 3 — Regulatory Matters for additional discussion of Mystic’s cost of service agreement.

As a result of the decision to early retire Mystic 8 and 9, there are financial impacts stemming from shortening the expected economic useful life of Mystic 8 and 9 primarily related to accelerated depreciation of plant assets. Exelon and Generation recorded incremental Depreciation and amortization expense of $20 million for the three months ended March 31, 2021.

8. Nuclear Decommissioning (Exelon and Generation)

Nuclear Decommissioning Asset Retirement Obligations

Generation has a legal obligation to decommission its nuclear power plants following the expiration of their operating licenses. To estimate its decommissioning obligation related to its nuclear generating stations for

77

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 8 — Nuclear Decommissioning

financial accounting and reporting purposes, Generation uses a probability-weighted, discounted cash flow model which, on a unit-by-unit basis, considers multiple outcome scenarios that include significant estimates and assumptions, and are based on decommissioning cost studies, cost escalation rates, probabilistic cash flow models, and discount rates. Generation updates its ARO annually, unless circumstances warrant more frequent updates, based on its review of updated cost studies and its annual evaluation of cost escalation factors and probabilities assigned to various scenarios.

The financial statement impact for changes in the ARO, on an individual unit basis, due to the changes in and timing of estimated cash flows generally result in a corresponding change in the unit’s ARC within Property, plant, and equipment on Exelon’s and Generation’s Consolidated Balance Sheets. If the ARO decreases for a Non-Regulatory Agreement unit without any remaining ARC, the corresponding change is recorded as decrease in Operating and maintenance expense within Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income.

The following table provides a rollforward of the nuclear decommissioning ARO reflected in Exelon’s and Generation’s Consolidated Balance Sheets from December 31, 2020 to March 31, 2021:

Nuclear decommissioning ARO at December 31, 2020(a)	$	11,922
Accretion expense	124
Costs incurred related to decommissioning plants	(20)
Nuclear decommissioning ARO at March 31, 2021(a)	$	12,026

_________

(a)Includes $80 million as the current portion of the ARO at March 31, 2021 and December 31, 2020, which is included in Other current liabilities in Exelon’s and Generation’s Consolidated Balance Sheets.

NDT Funds

Exelon and Generation had NDT funds totaling $14,927 million and $14,599 million at March 31, 2021 and December 31, 2020, respectively. The NDT funds also include $239 million and $134 million for the current portion of the NDT funds at March 31, 2021 and December 31, 2020, respectively, which are included in Other current assets in Exelon's and Generation's Consolidated Balance Sheets. See Note 17 — Supplemental Financial Information for additional information on activities of the NDT funds.

NRC Minimum Funding Requirements

NRC regulations require that licensees of nuclear generating facilities demonstrate reasonable assurance that funds will be available in specified minimum amounts to decommission the facility at the end of its life.

Generation filed its biennial decommissioning funding status report with the NRC on February 24, 2021 for all units, including its shutdown units, except for Zion Station which is included in a separate report to the NRC submitted by ZionSolutions, LLC. The status report demonstrated adequate decommissioning funding assurance as of December 31, 2020 for all units except for Byron Units 1 and 2. Generation stated that it intends to submit its PSDAR with additional decommissioning cost information by July 1, 2021, for Byron Units 1 and 2, and will evaluate the status of funding assurance based on the updated cost information and provide additional funding assurance by the time of shutdown if required.

Generation will file its next decommissioning funding status report with the NRC by March 31, 2022. This report will reflect the status of decommissioning funding assurance as of December 31, 2021 for shutdown units.

78

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 9 — Income Taxes

9. 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 March 31, 2021
	Exelon(a)	Generation(a)	ComEd(b)	PECO(b)	BGE(b),(c)	PHI(b)	Pepco(b)	DPL(b)	ACE(b)
U.S. Federal statutory rate	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	14.6	4.4	6.8	(1.6)	(10.1)	6.1	5.5	6.4	6.9
Qualified NDT fund income	(18.4)	(5.5)	—	—	—	—	—	—	—
Amortization of investment tax credit, including deferred taxes on basis difference	2.4	0.6	(0.1)	—	(0.1)	(0.1)	—	(0.2)	(0.2)
Plant basis differences	8.8	—	(0.6)	(10.5)	(1.4)	(1.5)	(2.1)	(0.7)	(0.9)
Production tax credits and other credits	6.7	1.8	(0.2)	—	(0.4)	(0.2)	(0.2)	(0.1)	(0.3)
Noncontrolling interests	0.6	0.2	—	—	—	—	—	—	—
Excess deferred tax amortization	27.9	—	(6.9)	(3.2)	(15.5)	(19.3)	(15.1)	(18.5)	(28.7)
Other(d)	(56.9)	(3.6)	(3.5)	(0.1)	(0.1)	(0.1)	0.1	0.3	2.2
Effective income tax rate	6.7%	18.9%	16.5%	5.6%	(6.6)%	5.9%	9.2%	8.2%	—%

	Three Months Ended March 31, 2020
	Exelon(b)	Generation(e)	ComEd(b)	PECO(b)	BGE(b)	PHI(b)	Pepco(b)	DPL(b)	ACE(b)
U.S. Federal statutory rate	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	34.0	0.7	8.3	0.1	5.7	5.8	4.7	6.6	6.7
Qualified NDT fund income	(235.8)	36.4	—	—	—	—	—	—	—
Amortization of investment tax credit, including deferred taxes on basis difference	(4.5)	0.5	(0.2)	—	(0.1)	(0.1)	—	(0.2)	(0.2)
Plant basis differences	(23.0)	—	(1.1)	(8.4)	(1.2)	(1.4)	(2.1)	(0.7)	(0.8)
Production tax credits and other credits	(9.9)	1.3	(0.2)	—	(0.2)	—	—	—	—
Noncontrolling interests	10.6	(1.6)	—	—	—	—	—	—	—
Excess deferred tax amortization	(71.7)	—	(10.5)	(3.0)	(7.3)	(15.5)	(14.2)	(12.7)	(18.8)
Tax Settlements	(79.1)	12.2	—	—	—	—	—	—	—
Other	12.5	0.6	0.3	—	0.6	(0.6)	(0.6)	(0.5)	(0.8)
Effective income tax rate	(345.9)%	71.1%	17.6%	9.7%	18.5%	9.2%	8.8%	13.5%	7.1%

79

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 9 — Income Taxes

__________

(a)Exelon and Generation recognized a loss before income taxes for the quarter ended March 31, 2021. As a result, positive percentages represent an income tax benefit for the period presented.

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

(c)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.

(d)For Exelon, "Other" is primarily driven by the consolidating income tax adjustment recorded at Exelon Corporate in the first quarter of 2021 that was required pursuant to GAAP interim reporting guidance. This incremental expense will reverse by year-end and will not have an impact on annual results.

(e)Generation recognized a loss before income taxes for the quarter ended March 31, 2020. As a result, positive percentages represent an income tax benefit for the period presented.

Unrecognized Tax Benefits

PHI and ACE have the following unrecognized tax benefits as of March 31, 2021 and December 31, 2020. Exelon's, Generation's, ComEd's, PECO's, BGE's, Pepco's, and DPL's amounts are not material.

	PHI		ACE
March 31, 2021	$	52	$	15
December 31, 2020	52		15

Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date

As of March 31, 2021, ACE has approximately $14 million of unrecognized state tax benefits that could significantly decrease within the 12 months after the reporting date based on the outcome of pending court cases involving other taxpayers. The unrecognized tax benefit, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate.

10. Retirement Benefits (All Registrants)

Defined Benefit Pension and OPEB

During the first quarter of 2021, Exelon received an updated valuation of its pension and OPEB to reflect actual census data as of January 1, 2021. This valuation resulted in an increase to the pension obligations of $33 million and a decrease to the OPEB obligations of $9 million. Additionally, accumulated other comprehensive loss increased by $1 million (after-tax) and regulatory assets and liabilities increased by $21 million and $1 million, respectively.

The majority of the 2021 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 2.58%. The majority of the 2021 OPEB cost is calculated using an expected long-term rate of return on plan assets of 6.46% for funded plans and a discount rate of 2.51%.

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 months ended March 31, 2021 and 2020.

80

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 10 — Retirement Benefits

	Pension Benefits				OPEB
	Three Months Ended March 31,				Three Months Ended March 31,
	2021		2020		2021		2020
Components of net periodic benefit cost:
Service cost	$	110	$	97	$	21	$	23
Interest cost	161		189		28		38
Expected return on assets	(336)		(318)		(40)		(41)
Amortization of:
Prior service cost (credit)	1		1		(8)		(31)
Actuarial loss	150		128		9		12
Curtailment benefits	—		—		(1)		—
Net periodic benefit cost	$	86	$	97	$	9	$	1

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 Generation and the Utility Registrants, the service cost and non-service cost components are included in Operating and maintenance expense and Property, plant, and equipment, net in their consolidated financial statements.

	Three Months Ended March 31,
Pension and OPEB Costs	2021		2020
Exelon	$	95	$	98
Generation	26		27
ComEd	32		28
PECO	2		1
BGE	15		16
PHI	12		17
Pepco	2		3
DPL	1		1
ACE	3		3

Defined Contribution Savings Plans

The Registrants participate in various 401(k) defined contribution savings plans that are sponsored by Exelon. The plans are 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 matching contributions to the savings plans for the three months ended March 31, 2021 and 2020, respectively.

	Three Months Ended March 31,
Savings Plans Matching Contributions	2021		2020
Exelon	$	33	$	33
Generation	13		13
ComEd	8		7
PECO	3		3
BGE	2		2
PHI	3		3
Pepco	1		1
DPL	1		1

81

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Derivative Financial Instruments

11. Derivative Financial Instruments (All Registrants)

The Registrants use derivative instruments to manage commodity price risk, interest rate risk, and foreign exchange risk related to ongoing business operations.

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. All derivative economic hedges related to commodities, referred to as economic hedges, are recorded at fair value through earnings at Generation and are offset by a corresponding regulatory asset or liability at ComEd. 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.

Authoritative guidance about offsetting assets and liabilities requires the fair value of derivative instruments to be shown in the Combined Notes to Consolidated Financial Statements on a gross basis, even when the derivative instruments are subject to legally enforceable master netting agreements and qualify for net presentation in the Consolidated Balance Sheets. A master netting agreement is an agreement between two counterparties that may have derivative and non-derivative contracts with each other providing for the net settlement of all referenced contracts via one payment stream, which takes place as the contracts deliver, when collateral is requested or in the event of default. In the tables below, which present fair value balances, Generation’s energy-related economic hedges and proprietary trading derivatives are shown gross. The impact of the netting of fair value balances with the same counterparty that are subject to legally enforceable master netting agreements, as well as netting of cash collateral, including margin on exchange positions, is aggregated in the collateral and netting columns.

Generation’s and ComEd’s use of cash collateral is generally unrestricted unless Generation or ComEd are 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 (All Registrants)

Each of the Registrants employ established policies and procedures to manage their risks associated with market fluctuations in commodity prices by entering into physical and financial derivative contracts, including swaps, futures, forwards, options, and short-term and long-term commitments to purchase and sell energy and commodity products. The Registrants believe these instruments, which are either determined to be non-derivative or classified as economic hedges, mitigate exposure to fluctuations in commodity prices.

Generation. To the extent the amount of energy Generation produces differs from the amount of energy it has contracted to sell, Exelon and Generation are exposed to market fluctuations in the prices of electricity, fossil fuels, and other commodities. Within Exelon, Generation has the most exposure to commodity price risk. As such, Generation uses a variety of derivative and non-derivative instruments to manage the commodity price risk of its electric generation facilities, including power and gas sales, fuel and power purchases, natural gas transportation and pipeline capacity agreements, and other energy-related products marketed and purchased. To manage these risks, Generation may enter into fixed-price derivative or non-derivative contracts to hedge the variability in future cash flows from expected sales of power and gas and purchases of power and fuel. The objectives for executing such hedges include fixing the price for a portion of anticipated future electricity sales at a level that provides an acceptable return. Generation is also exposed to differences between the locational settlement prices of certain economic hedges and the hedged generating units. This price difference is actively managed through other instruments which include derivative congestion products, whose changes in fair value are recognized in earnings each period, and auction revenue rights, which are accounted for on an accrual basis.

Additionally, Generation is exposed to certain market risks through its proprietary trading activities. The proprietary trading activities are a complement to Generation’s energy marketing portfolio but represent a small portion of Generation’s overall energy marketing activities and are subject to limits established by Exelon’s RMC.

Utility Registrants. 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’

82

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Derivative Financial Instruments

hedging programs are intended to reduce exposure to energy and natural gas price volatility and have no direct earnings impact as the costs are fully recovered from customers through 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 2020 Form 10-K for additional information.

(b)The fair value of the DPL economic hedge is not material as of March 31, 2021 and December 31, 2020 and is not presented in the fair value tables below.

The following table provides a summary of the derivative fair value balances recorded by Exelon, Generation, and ComEd as of March 31, 2021 and December 31, 2020:

	Exelon		Generation										ComEd
March 31, 2021	Total Derivatives		Economic Hedges		Proprietary Trading		Collateral(a)(b)		Netting(a)		Subtotal		Economic Hedges
Mark-to-market derivative assets (current assets)	$	569	$	2,566	$	28	$	24	$	(2,049)	$	569	$	—
Mark-to-market derivative assets (noncurrent assets)	488		1,400		5		45		(962)		488		—
Total mark-to-market derivative assets	1,057		3,966		33		69		(3,011)		1,057		—
Mark-to-market derivative liabilities (current liabilities)	(418)		(2,472)		(13)		49		2,049		(387)		(31)
Mark-to-market derivative liabilities (noncurrent liabilities)	(454)		(1,179)		(1)		28		962		(190)		(264)
Total mark-to-market derivative liabilities	(872)		(3,651)		(14)		77		3,011		(577)		(295)
Total mark-to-market derivative net assets (liabilities)	$	185	$	315	$	19	$	146	$	—	$	480	$	(295)

83

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Derivative Financial Instruments

	Exelon		Generation										ComEd
December 31, 2020	Total Derivatives		Economic Hedges		Proprietary Trading		Collateral(a)(b)		Netting(a)		Subtotal		Economic Hedges
Mark-to-market derivative assets (current assets)	$	639	$	2,757	$	40	$	103	$	(2,261)	$	639	$	—
Mark-to-market derivative assets (noncurrent assets)	554		1,501		4		64		(1,015)		554		—
Total mark-to-market derivative assets	1,193		4,258		44		167		(3,276)		1,193		—
Mark-to-market derivative liabilities (current liabilities)	(293)		(2,629)		(23)		131		2,261		(260)		(33)
Mark-to-market derivative liabilities (noncurrent liabilities)	(472)		(1,335)		(2)		118		1,015		(204)		(268)
Total mark-to-market derivative liabilities	(765)		(3,964)		(25)		249		3,276		(464)		(301)
Total mark-to-market derivative net assets (liabilities)	$	428	$	294	$	19	$	416	$	—	$	729	$	(301)

_________

(a)Exelon and Generation net all available amounts allowed under the derivative authoritative guidance in the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases Exelon and Generation may have other offsetting exposures, subject to a master netting or similar agreement, such as trade receivables and payables, transactions that do not qualify as derivatives, letters of credit, and other forms of non-cash collateral. These amounts are not material and not reflected in the table above.

(b)Of the collateral posted, $148 million and $209 million represents variation margin on the exchanges as of March 31, 2021 and December 31, 2020 respectively.

Economic Hedges (Commodity Price Risk)

Generation. For the three months ended March 31, 2021 and 2020, Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses) which are also located in the Net fair value changes related to derivatives line in the Consolidated Statements of Cash Flows.

	Three Months Ended March 31,
	2021		2020
Income Statement Location	Gain (Loss)
Operating revenues	$	(83)	$	175
Purchased power and fuel	265		(47)
Total Exelon and Generation	$	182	$	128

In general, increases and decreases in forward market prices have a positive and negative impact, respectively, on Generation’s owned and contracted generation positions that have not been hedged. Generation hedges commodity price risk on a ratable basis over three-year periods. As of March 31, 2021, the percentage of expected generation hedged for the Mid-Atlantic, Midwest, New York, and ERCOT reportable segments is 94%-97% for 2021.

Proprietary Trading (Commodity Price Risk)

Generation also executes commodity derivatives for proprietary trading purposes. Proprietary trading includes all contracts executed with the intent of benefiting from shifts or changes in market prices as opposed to those executed with the intent of hedging or managing risk. Gains and losses associated with proprietary trading are reported as Operating revenues in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income and are included in the Net fair value changes related to derivatives line in the Consolidated Statements of Cash Flows. For the three months ended March 31, 2021 and 2020, net pre-tax commodity mark-to-market gains and losses for Exelon and Generation were not material. The Utility Registrants do not execute derivatives for proprietary trading purposes.

84

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Derivative Financial Instruments

Interest Rate and Foreign Exchange Risk (Exelon and Generation)

Generation utilizes interest rate swaps to manage its interest rate exposure and foreign currency derivatives to manage foreign exchange rate exposure associated with international commodity purchases in currencies other than U.S. dollars, both of which are treated as economic hedges. The notional amounts were $563 million and $665 million for Exelon and Generation as of March 31, 2021 and December 31, 2020, respectively.

The mark-to-market derivative assets and liabilities as of March 31, 2021 and December 31, 2020 and the mark-to-market gains and losses for the three months ended March 31, 2021 and 2020 were not material for Exelon and Generation.

Credit Risk (All Registrants)

The Registrants would be exposed to credit-related losses in the event of non-performance by counterparties on executed derivative instruments. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date.

Generation. For commodity derivatives, Generation enters into enabling agreements that allow for payment netting with its counterparties, which reduces Generation’s exposure to counterparty risk by providing for the offset of amounts payable to the counterparty against amounts receivable from the counterparty. Typically, each enabling agreement is for a specific commodity and so, with respect to each individual counterparty, netting is limited to transactions involving that specific commodity product, except where master netting agreements exist with a counterparty that allow for cross product netting. In addition to payment netting language in the enabling agreement, Generation’s credit department establishes credit limits, margining thresholds, and collateral requirements for each counterparty, which are defined in the derivative contracts. Counterparty credit limits are based on an internal credit review process that considers a variety of factors, including the results of a scoring model, leverage, liquidity, profitability, credit ratings by credit rating agencies, and risk management capabilities. To the extent that a counterparty’s margining thresholds are exceeded, the counterparty is required to post collateral with Generation as specified in each enabling agreement. Generation’s credit department monitors current and forward credit exposure to counterparties and their affiliates, both on an individual and an aggregate basis.

85

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Derivative Financial Instruments

The following tables provide information on Generation’s credit exposure for all derivative instruments, NPNS, and payables and receivables, net of collateral and instruments that are subject to master netting agreements, as of March 31, 2021. The tables further delineate that exposure by credit rating of the counterparties and provide guidance on the concentration of credit risk to individual counterparties. The amounts in the tables below exclude credit risk exposure from individual retail counterparties, nuclear fuel procurement contracts, and exposure through RTOs, ISOs, NYMEX, ICE, NASDAQ, NGX, and Nodal commodity exchanges. 

Rating as of March 31, 2021	Total Exposure Before Credit Collateral		Credit Collateral(a)		Net Exposure		Number of Counterparties Greater than 10% of Net Exposure	Net Exposure of Counterparties Greater than 10% of Net Exposure
Investment grade	$	431	$	31	$	400	—	$	—
Non-investment grade	43		4		39
No external ratings
Internally rated — investment grade	146		1		145
Internally rated — non-investment grade	70		25		45
Total	$	690	$	61	$	629	—	$	—

Net Credit Exposure by Type of Counterparty	As of March 31, 2021
Investor-owned utilities, marketers, power producers	$	451
Energy cooperatives and municipalities	123
Other	55
Total	$	629

_________ 

(a)As of March 31, 2021, credit collateral held from counterparties where Generation had credit exposure included $32 million of cash and $29 million of letters of credit. The credit collateral does not include non-liquid collateral.

Utility Registrants. The Utility Registrants have contracts to procure electric and natural gas supply that provide suppliers with a certain amount of unsecured credit. If the exposure on the supply contract exceeds the amount of unsecured credit, the suppliers may be required to post collateral. The net credit exposure is mitigated primarily by the ability to recover procurement costs through customer rates. As of March 31, 2021, the Utility Registrants’ counterparty credit risk with suppliers was not material.

Credit-Risk-Related Contingent Features (All Registrants)

Generation. As part of the normal course of business, Generation routinely enters into physically or financially settled contracts for the purchase and sale of electric capacity, electricity, fuels, emissions allowances, and other energy-related products. Certain of Generation’s derivative instruments contain provisions that require Generation to post collateral. Generation also enters into commodity transactions on exchanges where the exchanges act as the counterparty to each trade. Transactions on the exchanges must adhere to comprehensive collateral and margining requirements. This collateral may be posted in the form of cash or credit support with thresholds contingent upon Generation’s credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty. These credit-risk-related contingent features stipulate that if Generation were to be downgraded or lose its investment grade credit rating (based on its senior unsecured debt rating), it would be required to provide additional collateral. This incremental collateral requirement allows for the offsetting of derivative instruments that are assets with the same counterparty, where the contractual right of offset exists under applicable master netting agreements. In the absence of expressly agreed-to provisions that specify the collateral that must be provided, collateral requested will be a function of the facts and circumstances of the situation at the time of the demand. In this case, Generation believes an amount of several months of future payments (i.e., capacity payments) rather than a calculation of fair value is the best estimate for the contingent collateral obligation, which has been factored into the disclosure below.

86

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 11 — Derivative Financial Instruments

The aggregate fair value of all derivative instruments with credit-risk related contingent features in a liability position that are not fully collateralized (excluding transactions on the exchanges that are fully collateralized) is detailed in the table below:

Credit-Risk Related Contingent Features	March 31, 2021		December 31, 2020
Gross fair value of derivative contracts containing this feature(a)	$	(948)	$	(834)
Offsetting fair value of in-the-money contracts under master netting arrangements(b)	518		537
Net fair value of derivative contracts containing this feature(c)	$	(430)	$	(297)

_________

(a)Amount represents the gross fair value of out-of-the-money derivative contracts containing credit-risk related contingent features ignoring the effects of master netting agreements.

(b)Amount represents the offsetting fair value of in-the-money derivative contracts under legally enforceable master netting agreements with the same counterparty, which reduces the amount of any liability for which Generation could potentially be required to post collateral.

(c)Amount represents the net fair value of out-of-the-money derivative contracts containing credit-risk related contingent features after considering the mitigating effects of offsetting positions under master netting arrangements and reflects the actual net liability upon which any potential contingent collateral obligations would be based.

As of March 31, 2021 and December 31, 2020, Exelon and Generation posted or held the following amounts of cash collateral and letters of credit on derivative contracts with external counterparties, after giving consideration to offsetting derivative and non-derivative positions under master netting agreements.

	March 31, 2021		December 31, 2020
Cash collateral posted	$	232	$	511
Letters of credit posted	242		226
Cash collateral held	101		110
Letters of credit held	41		40
Additional collateral required in the event of a credit downgrade below investment grade	1,379		1,432

Generation entered into supply forward contracts with certain utilities, including PECO and BGE, with one-sided collateral postings only from Generation. If market prices fall below the benchmark price levels in these contracts, the utilities are not required to post collateral. However, when market prices rise above the benchmark price levels, counterparty suppliers, including Generation, are required to post collateral once certain unsecured credit limits are exceeded.

Utility Registrants

The Utility Registrants’ electric supply procurement contracts do not contain provisions that would require them to post collateral.

PECO’s, BGE’s, and DPL’s natural gas procurement contracts contain provisions that could require PECO, BGE, and DPL to post collateral in the form of cash or credit support, which vary by contract and counterparty, with thresholds contingent upon PECO’s, BGE's, and DPL’s credit rating. As of March 31, 2021, PECO, BGE, and DPL were not required to post collateral for any of these agreements. If PECO, BGE, or DPL lost their investment grade credit rating as of March 31, 2021, they could have been required to post incremental collateral to its counterparties of $32 million, $48 million and $12 million, respectively.

87

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 12 — Debt and Credit Agreements

12. 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. Generation and PECO meet 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 the Exelon intercompany money pool. The Registrants may use their respective credit facilities for general corporate purposes, including meeting short-term funding requirements and the issuance of letters of credit.

Commercial Paper

The following table reflects the Registrants' commercial paper programs as of March 31, 2021 and December 31, 2020. PECO had no commercial paper borrowings as of both March 31, 2021 and December 31, 2020.

	Outstanding Commercial Paper as of				Average Interest Rate on Commercial Paper Borrowings as of
Commercial Paper Issuer	March 31, 2021		December 31, 2020		March 31, 2021		December 31, 2020
Exelon(a)(b)	$	1,628	$	1,031	0.52	%	0.25	%
Generation(b)	1,337		340		0.60	%	0.27	%
ComEd	135		323		0.16	%	0.23	%
BGE	156		—		0.15	%	—	%
PHI(c)	—		368		—	%	0.24	%
Pepco	—		35		—	%	0.22	%
DPL	—		146		—	%	0.24	%
ACE	—		187		—	%	0.25	%

__________

(a)Exelon Corporate had no outstanding commercial paper borrowings as of both March 31, 2021 and December 31, 2020.

(b)Higher outstanding commercial paper primarily driven by increased liquidity needs from the February 2021 extreme cold weather event. See Note 3 – Regulatory Matters for additional information.

(c)Represents the consolidated amounts of Pepco, DPL, and ACE.

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 17, 2021 and will expire on March 16, 2022. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR 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 24, 2021, Exelon Corporate entered into a 9-month term loan agreement for $200 million. The loan agreement has an expiration of December 24, 2021. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR 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 9-month and 364-day term loan agreement for $150 million each with variable interest rates of LIBOR plus 0.65% and expiration dates of December 31, 2021 and March 30, 2022, respectively. The loan agreements are reflected in Exelon's Consolidated Balance Sheets within Short-term borrowings.

On March 19, 2020, Generation entered into a term loan agreement for $200 million. The loan agreement was renewed on March 17, 2021 and will expire on March 16, 2022. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR plus 0.875% and all indebtedness thereunder is unsecured. The loan agreement is reflected in Exelon's and Generation's Consolidated Balance Sheets within Short-term borrowings.

88

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 12 — Debt and Credit Agreements

On March 31, 2020, Generation entered into a term loan agreement for $300 million. The loan agreement was renewed on March 30, 2021 and will expire on March 29, 2022. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR plus 0.70% and all indebtedness thereunder is unsecured. The loan agreement is reflected in Exelon's and Generation's Consolidated Balance Sheets within Short-term borrowings.

On January 25, 2021, ComEd entered into two 90-day term loan agreements for $125 million each with variable interest rates of LIBOR plus 0.50% and LIBOR plus 0.75%, respectively. ComEd repaid the term loans on March 9, 2021.

Bilateral Credit Agreements

On January 11, 2013, Generation entered into a bilateral credit agreement for $100 million. The agreement was renewed on March 1, 2021 with a maturity date of March 1, 2023.

On February 21, 2019, Generation entered into a bilateral credit agreement for $100 million. The agreement was renewed on March 31, 2021 with a maturity date of March 31, 2022.

On January 5, 2016, Generation entered into a bilateral credit agreement for $150 million. The agreement was renewed on April 2, 2021 with a maturity date of April 5, 2023.

Long-Term Debt

Issuance of Long-Term Debt

During the three months ended March 31, 2021, the following long-term debt was issued:

Company	Type	Interest Rate		Maturity	Amount		Use of Proceeds
Exelon	Long-Term Software License Agreements	3.62	%	December 1, 2025	$	4	Procurement of software licenses.
Generation	Energy Efficiency Project Financing(a)	2.53	%	May 31, 2021	1		Funding to install energy conservation measures for the Fort AP Hill project.
ComEd	First Mortgage Bonds, Series 130	3.13	%	March 15, 2051	700		Repay a portion of outstanding commercial paper obligations and two outstanding term loans, and to fund other general corporate purposes.
PECO	First and Refunding Mortgage Bonds	3.05	%	March 15, 2051	375		Funding for general corporate purposes.
Pepco(b)	First Mortgage Bonds	2.32	%	March 30, 2031	150		Repay existing indebtedness and for general corporate purposes.
DPL	First Mortgage Bonds	3.24	%	March 30, 2051	125		Repay existing indebtedness and for general corporate purposes.
ACE	First Mortgage Bonds	2.30	%	March 15, 2031	350		Refinance existing indebtedness, repay outstanding commercial paper obligations, and for general corporate purposes.

__________

(a)For Energy Efficiency Project Financing, the maturity dates represent the expected date of project completion, upon which the respective customer assumes the outstanding debt.

(b)On March 30, 2021, Pepco entered into a purchase agreement of First Mortgage Bonds of $125 million at 3.29% due on September 28, 2051. The closing date of the issuance is expected to occur in September 2021.

Debt Covenants

As of March 31, 2021, the Registrants are in compliance with debt covenants.

89

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — Fair Value of Financial Assets and Liabilities

13. 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, SNF obligation, and trust preferred securities (long-term debt to financing trusts or junior subordinated debentures) as of March 31, 2021 and December 31, 2020. The Registrants have no financial liabilities classified as Level 1.

The carrying amounts of the Registrants’ short-term liabilities as presented on their Consolidated Balance Sheets are representative of their fair value (Level 2) because of the short-term nature of these instruments.

	March 31, 2021								December 31, 2020
	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	$	38,529	$	39,255	$	3,115	$	42,370	$	36,912	$	40,688	$	3,064	$	43,752
Generation	6,060		5,497		1,158		6,655		6,087		5,648		1,208		6,856
ComEd	9,674		10,853		—		10,853		8,983		11,117		—		11,117
PECO	4,125		4,491		50		4,541		3,753		4,553		50		4,603
BGE	3,665		3,991		—		3,991		3,664		4,366		—		4,366
PHI	7,577		6,050		1,907		7,957		7,006		6,099		1,806		7,905
Pepco	3,317		3,112		823		3,935		3,165		3,336		748		4,084
DPL	1,802		1,386		524		1,910		1,677		1,484		455		1,939
ACE	1,718		1,302		560		1,862		1,413		1,018		602		1,620
Long-Term Debt to Financing Trusts(a)
Exelon	$	390	$	—	$	465	$	465	$	390	$	—	$	467	$	467
ComEd	205		—		243		243		205		—		246		246
PECO	184		—		222		222		184		—		221		221
SNF Obligation
Exelon	$	1,208	$	979	$	—	$	979	$	1,208	$	909	$	—	$	909
Generation	1,208		979		—		979		1,208		909		—		909

__________

(a)Includes unamortized debt issuance costs which are not fair valued.

90

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — Fair Value of Financial Assets and Liabilities

Recurring Fair Value Measurements

The following tables present assets and liabilities measured and recorded at fair value in the Registrants' Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of March 31, 2021 and December 31, 2020:

Exelon and Generation

	Exelon										Generation
As of March 31, 2021	Level 1		Level 2		Level 3		Not subject to leveling		Total		Level 1		Level 2		Level 3		Not subject to leveling		Total
Assets
Cash equivalents(a)	$	968	$	—	$	—	$	—	$	968	$	125	$	—	$	—	$	—	$	125
NDT fund investments
Cash equivalents(b)	509		95		—		—		604		509		95		—		—		604
Equities	4,439		1,574		—		1,555		7,568		4,439		1,574		—		1,555		7,568
Fixed income
Corporate debt(c)	—		1,023		283		—		1,306		—		1,023		283		—		1,306
U.S. Treasury and agencies	2,030		41		—		—		2,071		2,030		41		—		—		2,071
Foreign governments	—		51		—		—		51		—		51		—		—		51
State and municipal debt	—		40		—		—		40		—		40		—		—		40
Other	40		35		—		1,285		1,360		40		35		—		1,285		1,360
Fixed income subtotal	2,070		1,190		283		1,285		4,828		2,070		1,190		283		1,285		4,828
Private credit	—		—		196		617		813		—		—		196		617		813
Private equity	—		—		—		532		532		—		—		—		532		532
Real estate	—		—		—		686		686		—		—		—		686		686
NDT fund investments subtotal(d)(e)	7,018		2,859		479		4,675		15,031		7,018		2,859		479		4,675		15,031
Rabbi trust investments
Cash equivalents	60		—		—		—		60		4		—		—		—		4
Mutual funds	95		—		—		—		95		31		—		—		—		31
Fixed income	—		10		—		—		10		—		—		—		—		—
Life insurance contracts	—		89		35		—		124		—		29		—		—		29
Rabbi trust investments subtotal	155		99		35		—		289		35		29		—		—		64
Investments in equities(f)	177		—		—		—		177		177		—		—		—		177
Commodity derivative assets
Economic hedges	478		1,748		1,740		—		3,966		478		1,748		1,740		—		3,966
Proprietary trading	—		16		17		—		33		—		16		17		—		33
Effect of netting and allocation of collateral(g)(h)	(356)		(1,387)		(1,199)		—		(2,942)		(356)		(1,387)		(1,199)		—		(2,942)
Commodity derivative assets subtotal	122		377		558		—		1,057		122		377		558		—		1,057
DPP consideration	—		401		—		—		401		—		401		—		—		401

91

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — Fair Value of Financial Assets and Liabilities

	Exelon										Generation
As of March 31, 2021	Level 1		Level 2		Level 3		Not subject to leveling		Total		Level 1		Level 2		Level 3		Not subject to leveling		Total
Total assets	8,440		3,736		1,072		4,675		17,923		7,477		3,666		1,037		4,675		16,855
Liabilities
Commodity derivative liabilities
Economic hedges	(359)		(1,642)		(1,945)		—		(3,946)		(359)		(1,642)		(1,650)		—		(3,651)
Proprietary trading	—		(9)		(5)		—		(14)		—		(9)		(5)		—		(14)
Effect of netting and allocation of collateral(g)(h)	252		1,532		1,304		—		3,088		252		1,532		1,304		—		3,088
Commodity derivative liabilities subtotal	(107)		(119)		(646)		—		(872)		(107)		(119)		(351)		—		(577)
Deferred compensation obligation	—		(146)		—		—		(146)		—		(43)		—		—		(43)
Total liabilities	(107)		(265)		(646)		—		(1,018)		(107)		(162)		(351)		—		(620)
Total net assets	$	8,333	$	3,471	$	426	$	4,675	$	16,905	$	7,370	$	3,504	$	686	$	4,675	$	16,235

92

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — Fair Value of Financial Assets and Liabilities

	Exelon										Generation
As of December 31, 2020	Level 1		Level 2		Level 3		Not subject to leveling		Total		Level 1		Level 2		Level 3		Not subject to leveling		Total
Assets
Cash equivalents(a)	$	686	$	—	$	—	$	—	$	686	$	124	$	—	$	—	$	—	$	124
NDT fund investments
Cash equivalents(b)	210		95		—		—		305		210		95		—		—		305
Equities	3,886		2,077		—		1,562		7,525		3,886		2,077		—		1,562		7,525
Fixed income
Corporate debt(c)	—		1,485		285		—		1,770		—		1,485		285		—		1,770
U.S. Treasury and agencies	1,871		126		—		—		1,997		1,871		126		—		—		1,997
Foreign governments	—		56		—		—		56		—		56		—		—		56
State and municipal debt	—		101		—		—		101		—		101		—		—		101
Other	—		41		—		961		1,002		—		41		—		961		1,002
Fixed income subtotal	1,871		1,809		285		961		4,926		1,871		1,809		285		961		4,926
Private credit	—		—		212		629		841		—		—		212		629		841
Private equity	—		—		—		504		504		—		—		—		504		504
Real estate	—		—		—		679		679		—		—		—		679		679
NDT fund investments subtotal(d)(e)	5,967		3,981		497		4,335		14,780		5,967		3,981		497		4,335		14,780
Rabbi trust investments
Cash equivalents	60		—		—		—		60		4		—		—		—		4
Mutual funds	91		—		—		—		91		29		—		—		—		29
Fixed income	—		11		—		—		11		—		—		—		—		—
Life insurance contracts	—		87		34		—		121		—		28		—		—		28
Rabbi trust investments subtotal	151		98		34		—		283		33		28		—		—		61
Investments in equities(f)	195		—		—		—		195		195		—		—		—		195
Commodity derivative assets
Economic hedges	745		1,914		1,599		—		4,258		745		1,914		1,599		—		4,258
Proprietary trading	—		17		27		—		44		—		17		27		—		44
Effect of netting and allocation of collateral(g)(h)	(607)		(1,597)		(905)		—		(3,109)		(607)		(1,597)		(905)		—		(3,109)
Commodity derivative assets subtotal	138		334		721		—		1,193		138		334		721		—		1,193
DPP consideration	—		639		—		—		639		—		639		—		—		639
Total assets	7,137		5,052		1,252		4,335		17,776		6,457		4,982		1,218		4,335		16,992
Liabilities
Commodity derivative liabilities
Economic hedges	(682)		(1,928)		(1,655)		—		(4,265)		(682)		(1,928)		(1,354)		—		(3,964)
Proprietary trading	—		(21)		(4)		—		(25)		—		(21)		(4)		—		(25)
Effect of netting and allocation of collateral(g)(h)	540		1,918		1,067		—		3,525		540		1,918		1,067		—		3,525
Commodity derivative liabilities subtotal	(142)		(31)		(592)		—		(765)		(142)		(31)		(291)		—		(464)
Deferred compensation obligation	—		(145)		—		—		(145)		—		(42)		—		—		(42)
Total liabilities	(142)		(176)		(592)		—		(910)		(142)		(73)		(291)		—		(506)
Total net assets	$	6,995	$	4,876	$	660	$	4,335	$	16,866	$	6,315	$	4,909	$	927	$	4,335	$	16,486

__________    

93

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — Fair Value of Financial Assets and Liabilities

(a)Exelon excludes cash of $1,273 million and $409 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $93 million and $59 million at March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $52 million and $53 million at March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. Generation excludes cash of $608 million and $171 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $29 million and $20 million at March 31, 2021 and December 31, 2020, respectively. 

(b)Includes $108 million and $116 million of cash received from outstanding repurchase agreements at March 31, 2021 and December 31, 2020, respectively, and is offset by an obligation to repay upon settlement of the agreement as discussed in (e) below.

(c)Includes investments in equities sold short of $(58) million and $(62) million as of March 31, 2021 and December 31, 2020, respectively, held in an investment vehicle primarily to hedge the equity option component of its convertible debt.

(d)Includes derivative assets of less than $1 million and $2 million, which have total notional amounts of $2,049 million and $1,043 million at March 31, 2021 and December 31, 2020, respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the periods ended and do not represent the amount of Exelon and Generation's exposure to credit or market loss.

(e)Excludes net liabilities of $104 million and $181 million at March 31, 2021 and December 31, 2020, respectively, which include certain derivative assets that have notional amounts of $158 million and $104 million at March 31, 2021 and December 31, 2020, respectively. These items consist of receivables related to pending securities sales, interest and dividend receivables, repurchase agreement obligations, and payables related to pending securities purchases. The repurchase agreements are generally short-term in nature with durations generally of 30 days or less.

(f)Includes equity investments held by Generation which were previously designated as equity investments without readily determinable fair value but are now publicly traded and therefore have readily determinable fair values. Generation recorded the fair value of these investments in Other current assets on Exelon's and Generation's Consolidated Balance Sheets based on the quoted market prices of the stocks at March 31, 2021 and December 31, 2020, which resulted in unrealized gains of $95 million and $186 million within Other, net in Exelon's and Generation's Consolidated Statement of Operations and Comprehensive Income for the three months ended March 31, 2021 and for the year ended December 31, 2020, respectively.

(g)Collateral (received)/posted from counterparties, net of collateral paid to counterparties, totaled $(104) million, $145 million, and $105 million allocated to Level 1, Level 2, and Level 3 mark-to-market derivatives, respectively, as of March 31, 2021. Collateral (received)/posted from counterparties, net of collateral paid to counterparties, totaled $(67) million, $321 million, and $162 million allocated to Level 1, Level 2, and Level 3 mark-to-market derivatives, respectively, as of December 31, 2020.

(h)Of the collateral (received)/posted, $(148) million and $209 million represents variation margin on the exchanges as of March 31, 2021 and December 31, 2020, respectively.

As of March 31, 2021, Exelon and Generation have outstanding commitments to invest in private credit, private equity, and real estate investments of approximately $298 million, $239 million, and $344 million, respectively. These commitments will be funded by Generation’s existing NDT funds.

Exelon and Generation hold investments without readily determinable fair values with carrying amounts of $61 million and $50 million as of March 31, 2021, respectively. Changes in fair value, cumulative adjustments, and impairments were not material for the three months ended March 31, 2021.

94

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — Fair Value of Financial Assets and Liabilities

ComEd, PECO, and BGE

	ComEd								PECO								BGE
As of March 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)	$	300	$	—	$	—	$	300	$	7	$	—	$	—	$	7	$	—	$	—	$	—	$	—
Rabbi trust investments
Mutual funds	—		—		—		—		9		—		—		9		11		—		—		11
Life insurance contracts	—		—		—		—		—		13		—		13		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		9		13		—		22		11		—		—		11
Total assets	300		—		—		300		16		13		—		29		11		—		—		11
Liabilities
Deferred compensation obligation	—		(8)		—		(8)		—		(9)		—		(9)		—		(6)		—		(6)
Mark-to-market derivative liabilities(b)	—		—		(295)		(295)		—		—		—		—		—		—		—		—
Total liabilities	—		(8)		(295)		(303)		—		(9)		—		(9)		—		(6)		—		(6)
Total net assets (liabilities)	$	300	$	(8)	$	(295)	$	(3)	$	16	$	4	$	—	$	20	$	11	$	(6)	$	—	$	5

	ComEd								PECO								BGE
As of December 31, 2020	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)	$	285	$	—	$	—	$	285	$	8	$	—	$	—	$	8	$	120	$	—	$	—	$	120
Rabbi trust investments
Mutual funds	—		—		—		—		9		—		—		9		10		—		—		10
Life insurance contracts	—		—		—		—		—		13		—		13		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		9		13		—		22		10		—		—		10
Total assets	285		—		—		285		17		13		—		30		130		—		—		130
Liabilities
Deferred compensation obligation	—		(8)		—		(8)		—		(9)		—		(9)		—		(5)		—		(5)
Mark-to-market derivative liabilities(b)	—		—		(301)		(301)		—		—		—		—		—		—		—		—
Total liabilities	—		(8)		(301)		(309)		—		(9)		—		(9)		—		(5)		—		(5)
Total net assets (liabilities)	$	285	$	(8)	$	(301)	$	(24)	$	17	$	4	$	—	$	21	$	130	$	(5)	$	—	$	125

__________

(a)ComEd excludes cash of $59 million and $83 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $40 million and $37 million at March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $43 million at both March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. PECO excludes cash of $48 million and $18 million at March 31, 2021 and December 31, 2020, respectively. BGE excludes cash of $21 million and $24 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $1 million at both March 31, 2021 and December 31, 2020.

(b)The Level 3 balance consists of the current and noncurrent liability of $31 million and $264 million, respectively, at March 31, 2021 and $33 million and $268 million, respectively, at December 31, 2020 related to floating-to-fixed energy swap contracts with unaffiliated suppliers.

95

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — Fair Value of Financial Assets and Liabilities

PHI, Pepco, DPL, and ACE

	As of March 31, 2021								As of December 31, 2020
PHI	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	527	$	—	$	—	$	527	$	86	$	—	$	—	$	86
Rabbi trust investments
Cash equivalents	53		—		—		53		55		—		—		55
Mutual funds	15		—		—		15		14		—		—		14
Fixed income	—		10		—		10		—		11		—		11
Life insurance contracts	—		26		35		61		—		26		34		60
Rabbi trust investments subtotal	68		36		35		139		69		37		34		140
Total assets	595		36		35		666		155		37		34		226
Liabilities
Deferred compensation obligation	—		(16)		—		(16)		—		(17)		—		(17)
Total liabilities	—		(16)		—		(16)		—		(17)		—		(17)
Total net assets	$	595	$	20	$	35	$	650	$	155	$	20	$	34	$	209

	Pepco								DPL								ACE
As of March 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)	$	128	$	—	$	—	$	128	$	50	$	—	$	—	$	50	$	349	$	—	$	—	$	349
Rabbi trust investments
Cash equivalents	53		—		—		53		—		—		—		—		—		—		—		—
Fixed income	—		2		—		2		—		—		—		—		—		—		—		—
Life insurance contracts	—		26		35		61		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	53		28		35		116		—		—		—		—		—		—		—		—
Total assets	181		28		35		244		50		—		—		50		349		—		—		349
Liabilities
Deferred compensation obligation	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total liabilities	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total net assets	$	181	$	26	$	35	$	242	$	50	$	—	$	—	$	50	$	349	$	—	$	—	$	349

96

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — Fair Value of Financial Assets and Liabilities

	Pepco								DPL								ACE
As of December 31, 2020	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)	$	35	$	—	$	—	$	35	$	—	$	—	$	—	$	—	$	13	$	—	$	—	$	13
Rabbi trust investments
Cash equivalents	53		—		—		53		—		—		—		—		—		—		—		—
Fixed income	—		2		—		2		—		—		—		—		—		—		—		—
Life insurance contracts	—		26		34		60		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	53		28		34		115		—		—		—		—		—		—		—		—
Total assets	88		28		34		150		—		—		—		—		13		—		—		13
Liabilities
Deferred compensation obligation	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total liabilities	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total net assets	$	88	$	26	$	34	$	148	$	—	$	—	$	—	$	—	$	13	$	—	$	—	$	13

__________

(a)PHI excludes cash of $72 million and $74 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $5 million and none at March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $9 million and $10 million at March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. Pepco excludes cash of $34 million and $30 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $5 million and none at March 31, 2021 and December 31, 2020, respectively. DPL excludes cash of $14 million and $15 million at March 31, 2021 and December 31, 2020, respectively. ACE excludes cash of $17 million at both March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $9 million and $10 million at March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets.

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 months ended March 31, 2021 and 2020:

	Exelon		Generation							ComEd			PHI and Pepco
Three months ended March 31, 2021	Total		NDT Fund Investments		Mark-to-Market Derivatives			Total Generation		Mark-to-Market Derivatives			Life Insurance Contracts		Eliminated in Consolidation
Balance as of December 31, 2020	$	660	$	497	$	430		$	927	$	(301)		$	34	$	—
Total realized / unrealized gains (losses)
Included in net income	(276)		1		(278)		(a)	(277)		—			1		—
Included in noncurrent payables to affiliates	—		1		—			1		—			—		(1)
Included in regulatory assets	7		—		—			—		6		(b)	—		1
Change in collateral	(57)		—		(57)			(57)		—			—		—
Purchases, sales, issuances and settlements
Purchases	109		—		109			109		—			—		—
Sales	1		—		1			1		—			—		—
Settlements	(20)		(20)		—			(20)		—			—		—
Transfers out of Level 3	2		—		2		(c)	2		—			—		—
Balance as of March 31, 2021	$	426	$	479	$	207		$	686	$	(295)		$	35	$	—
The amount of total (losses) gains included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of March 31, 2021	$	(147)	$	1	$	(149)		$	(148)	$	—		$	1	$	—

97

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — Fair Value of Financial Assets and Liabilities

	Exelon		Generation							ComEd			PHI and Pepco
Three Months Ended March 31, 2020	Total		NDT Fund Investments		Mark-to-Market Derivatives			Total Generation		Mark-to-Market Derivatives			Life Insurance Contracts		Eliminated in Consolidation
Balance as of December 31, 2019	$	1,068	$	511	$	817		$	1,328	$	(301)		$	41	$	—
Total realized / unrealized gains (losses)
Included in net income	10		(1)		10		(a)	9		—			1		—
Included in noncurrent payables to affiliates	—		(1)		—			(1)		—			—		1
Included in regulatory assets	(14)		—		—			—		(13)		(b)	—		(1)
Change in collateral	1		—		1			1		—			—		—
Purchases, sales, issuances and settlements
Purchases	42		3		39			42		—			—		—
Sales	(22)		—		(22)			(22)		—			—		—
Settlements	(14)		(14)		—			(14)		—			—		—
Transfers into Level 3	2		—		2		(c)	2		—			—		—
Transfers out of Level 3	15		—		15		(c)	15		—			—		—
Balance as of March 31, 2020	$	1,088	$	498	$	862		$	1,360	$	(314)		$	42	$	—
The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of March 31, 2020	$	187	$	(1)	$	187		$	186	$	—		$	1	$	—

__________

(a)Includes a reduction for the reclassification of $129 million and $177 million of realized losses due to the settlement of derivative contracts for the three months ended March 31, 2021 and 2020 respectively.

(b)Includes $2 million of decreases in fair value and an increase for realized losses due to settlements of $8 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended March 31, 2021. Includes $23 million of decrease in fair value and an increase for realized losses due to settlements of $10 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended March 31, 2020.

(c)Transfers into and out of Level 3 generally occur when the contract tenor becomes less and more observable respectively, primarily due to changes in market liquidity or assumptions for certain commodity contracts.

The following tables present the income statement classification of the total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis during the three months ended March 31, 2021 and 2020:

	Exelon								Generation						PHI and Pepco
	Operating Revenues		Purchased Power and Fuel		Operating and Maintenance		Other, net		Operating Revenues		Purchased Power and Fuel		Other, net		Operating and Maintenance
Total (losses) gains for the three months ended March 31, 2021	$	(116)	$	(162)	$	1	$	1	$	(116)	$	(162)	$	1	$	1
Total unrealized (losses) gains for the three months ended March 31, 2021	(65)		(84)		1		1		(65)		(84)		1		1

	Exelon								Generation						PHI and Pepco
	Operating Revenues		Purchased Power and Fuel		Operating and Maintenance		Other, net		Operating Revenues		Purchased Power and Fuel		Other, net		Operating and Maintenance
Total gains (losses) for the three months ended March 31, 2020	$	72	$	(62)	$	1	$	(1)	$	72	$	(62)	$	(1)	$	1
Total unrealized gains (losses) gains for the three months ended March 31, 2020	205		(18)		1		(1)		205		(18)		(1)		1

98

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — 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 18 — Fair Value of Financial Assets and Liabilities of the Exelon 2020 Form 10-K.

Valuation Techniques Used to Determine Net asset Value (Exelon and Generation)

Certain NDT Fund Investments are not classified within the fair value hierarchy and are included under the heading “Not subject to leveling” in the table above. These investments are measured at fair value using NAV per share as a practical expedient and include commingled funds, mutual funds which are not publicly quoted, managed private credit funds, private equity and real estate funds.

For commingled funds and mutual funds, which are not publicly quoted, the fair value is primarily derived from the quoted prices in active markets on the underlying securities and can typically be redeemed monthly with 30 or less days of notice and without further restrictions. For managed private credit funds, the fair value is determined using a combination of valuation models including cost models, market models, and income models and typically cannot be redeemed until maturity of the term loan. Private equity and real estate investments include those in limited partnerships that invest in operating companies and real estate holding companies that are not publicly traded on a stock exchange, such as, leveraged buyouts, growth capital, venture capital, distressed investments, investments in natural resources, and direct investments in pools of real estate properties. These investments typically cannot be redeemed and are generally liquidated over a period of 8 to 10 years from the initial investment date, which is based on Exelon’s understanding of the investment funds. Private equity and real estate valuations are reported by the fund manager and are based on the valuation of the underlying investments, which include inputs such as cost, operating results, discounted future cash flows, market based comparable data, and independent appraisals from sources with professional qualifications. These valuation inputs are unobservable.

Mark-to-Market Derivatives (Exelon, Generation and ComEd)

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

Type of trade	Fair Value at March 31, 2021		Fair Value at December 31, 2020		Valuation Technique	Unobservable Input	2021 Range & Arithmetic Average				2020 Range & Arithmetic Average
Mark-to-market derivatives — Economic Hedges (Exelon and Generation)(a)(b)	$	90	$	245	Discounted Cash Flow	Forward power price	$1.35	-	$235	$32	$2.25	-	$163	$30
						Forward gas price	$1.42	-	$8.18	$2.59	$1.57	-	$7.88	$2.59
					Option Model	Volatility percentage	11%	-	116%	27%	11%	-	237%	32%
Mark-to-market derivatives — Proprietary trading (Exelon and Generation)(a)(b)	$	12	$	23	Discounted Cash Flow	Forward power price	$9	-	$102	$30	$10	-	$106	$27
Mark-to-market derivatives (Exelon and ComEd)	$	(295)	$	(301)	Discounted Cash Flow	Forward heat rate(c)	8x	-	9x	8.85x	8x	-	9x	8.85x
						Marketability reserve	3%	-	8%	4.93%	3%	-	8%	4.93%
						Renewable factor	90%	-	123%	99%	91%	-	123%	99%

__________

(a)The valuation techniques, unobservable inputs, ranges and arithmetic averages are the same for the asset and liability positions.

(b)The fair values do not include cash collateral posted on level three positions of $105 million and $162 million as of March 31, 2021 and December 31, 2020, respectively.

(c)Quoted forward natural gas rates are utilized to project the forward power curve for the delivery of energy at specified future dates. The natural gas curve is extrapolated beyond its observable period to the end of the contract’s delivery.

99

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 13 — Fair Value of Financial Assets and Liabilities

The inputs listed above, which are as of the balance sheet date, would have a direct impact on the fair values of the above instruments if they were adjusted. The significant unobservable inputs used in the fair value measurement of Generation’s commodity derivatives are forward commodity prices and for options is price volatility. Increases (decreases) in the forward commodity price in isolation would result in significantly higher (lower) fair values for long positions (contracts that give Generation the obligation or option to purchase a commodity), with offsetting impacts to short positions (contracts that give Generation the obligation or right to sell a commodity). Increases (decreases) in volatility would increase (decrease) the value for the holder of the option (writer of the option). Generally, a change in the estimate of forward commodity prices is unrelated to a change in the estimate of volatility of prices. An increase to the reserves listed above would decrease the fair value of the positions. An increase to the heat rate or renewable factors would increase the fair value accordingly. Generally, interrelationships exist between market prices of natural gas and power. As such, an increase in natural gas pricing would potentially have a similar impact on forward power markets.

14. Commitments and Contingencies (All Registrants)

The following is an update to the current status of commitments and contingencies set forth in Note 19 of the Exelon 2020 Form 10-K.

Commitments

PHI Merger Commitments (Exelon, PHI, Pepco, DPL and ACE). Approval of the PHI Merger in Delaware, New Jersey, Maryland and the District of Columbia was conditioned upon Exelon and PHI agreeing to certain commitments. The following amounts represent total commitment costs that have been recorded since the acquisition date and the total remaining obligations for Exelon, PHI, Pepco, DPL, and ACE as of March 31, 2021:

Description	Exelon		PHI		Pepco		DPL		ACE
Total commitments	$	513	$	320	$	120	$	89	$	111
Remaining commitments(a)	79		64		53		7		4

__________

(a)Remaining commitments extend through 2026 and include rate credits, energy efficiency programs and delivery system modernization.

In addition, Exelon is committed to develop or to assist in the commercial development of approximately 37 MWs of new solar generation in Maryland, District of Columbia, and Delaware at an estimated cost of approximately $135 million, which will generate future earnings at Exelon and Generation. Investment costs, which are expected to be primarily capital in nature, are recognized as incurred and recorded in Exelon's and Generation's financial statements. As of March 31, 2021, 27 MWs of new generation were developed and Exelon and Generation have incurred costs of $121 million. Exelon has also committed to purchase 100 MWs of wind energy in PJM. DPL has committed to conducting three RFPs to procure up to a total of 120 MWs of wind RECs for the purpose of meeting Delaware's renewable portfolio standards. DPL has conducted two of the three wind REC RFPs. The first 40 MW wind REC tranche was conducted in 2017 and did not result in a purchase agreement. The second 40 MW wind REC tranche was conducted in 2018 and resulted in a proposed REC purchase agreement that was approved by the DPSC in 2019. The third and final 40 MW wind REC tranche will be conducted in 2022.

100

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 14 — Commitments and Contingencies

Commercial Commitments (All Registrants). The Registrants’ commercial commitments as of March 31, 2021, representing commitments potentially triggered by future events were as follows:

			Expiration within
	Total		2021		2022		2023		2024		2025		2026 and beyond
Exelon
Letters of credit	$	1,639	$	1,156	$	483	$	—	$	—	$	—	$	—
Surety bonds(a)	1,077		919		158		—		—		—		—
Financing trust guarantees	378		—		—		—		—		—		378
Guaranteed lease residual values(b)	29		—		3		4		6		5		11
Total commercial commitments	$	3,123	$	2,075	$	644	$	4	$	6	$	5	$	389
Generation
Letters of credit	$	1,623	$	1,141	$	482	$	—	$	—	$	—	$	—
Surety bonds(a)	932		794		138		—		—		—		—
Total commercial commitments	$	2,555	$	1,935	$	620	$	—	$	—	$	—	$	—
ComEd
Letters of credit	$	7	$	7	$	—	$	—	$	—	$	—	$	—
Surety bonds(a)	17		14		3		—		—		—		—
Financing trust guarantees	200		—		—		—		—		—		200
Total commercial commitments	$	224	$	21	$	3	$	—	$	—	$	—	$	200
PECO
Surety bonds(a)	$	2	$	2	$	—	$	—	$	—	$	—	$	—
Financing trust guarantees	178		—		—		—		—		—		178
Total commercial commitments	$	180	$	2	$	—	$	—	$	—	$	—	$	178
BGE
Letters of credit	$	3	$	2	$	1	$	—	$	—	$	—	$	—
Surety bonds(a)	3		3		—		—		—		—		—
Total commercial commitments	$	6	$	5	$	1	$	—	$	—	$	—	$	—
PHI
Surety bonds(a)	$	23	$	20	$	3	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	29		—		3		4		6		5		11
Total commercial commitments	$	52	$	20	$	6	$	4	$	6	$	5	$	11
Pepco
Surety bonds(a)	$	14	$	14	$	—	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	10		—		1		1		2		2		4
Total commercial commitments	$	24	$	14	$	1	$	1	$	2	$	2	$	4
DPL
Surety bonds(a)	$	5	$	2	$	3	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	12		—		1		2		3		2		4
Total commercial commitments	$	17	$	2	$	4	$	2	$	3	$	2	$	4
ACE
Surety bonds(a)	$	4	$	4	$	—	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	7		—		1		1		1		1		3
Total commercial commitments	$	11	$	4	$	1	$	1	$	1	$	1	$	3

__________

(a)Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds.

101

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 14 — Commitments and Contingencies

(b)Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The lease term associated with these assets ranges from 1 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $73 million guaranteed by Exelon and PHI, of which $25 million, $30 million, and $18 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 (Exelon and the Utility Registrants). ComEd, PECO, BGE, and DPL have identified sites where former MGP or gas purification activities have or may have resulted in actual site contamination. For almost all of these sites, there are additional PRPs that may share responsibility for the ultimate remediation of each location.

•ComEd has 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 2026.

•PECO has 8 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 settlements of natural gas distribution rate cases with the PAPUC, 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.

102

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 14 — Commitments and Contingencies

As of March 31, 2021 and December 31, 2020, the Registrants had accrued the following undiscounted amounts for environmental liabilities in Other current liabilities and Other deferred credits and other liabilities within their respective Consolidated Balance Sheets:

	March 31, 2021				December 31, 2020
	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	$	473	$	306	$	483	$	314
Generation	119		—		121		—
ComEd	281		280		293		293
PECO	23		21		23		21
BGE	6		5		2		—
PHI	44		—		44		—
Pepco	42		—		42		—
DPL	1		—		1		—
ACE	1		—		1		—

Cotter Corporation (Exelon and Generation). The EPA has advised Cotter Corporation (Cotter), a former ComEd subsidiary, that it is potentially liable in connection with radiological contamination at a site known as the West Lake Landfill in Missouri. In 2000, ComEd sold Cotter to an unaffiliated third-party. As part of the sale, ComEd agreed to indemnify Cotter for any liability arising in connection with the West Lake Landfill. In connection with Exelon’s 2001 corporate restructuring, this responsibility to indemnify Cotter was transferred to Generation. Including Cotter, there are three PRPs participating in the West Lake Landfill remediation proceeding. Investigation by Generation has identified a number of other parties who also may be PRPs and could be liable to contribute to the final remedy. Further investigation is ongoing.

In September 2018, the EPA issued its Record of Decision Amendment (RODA) for the selection of a final remedy. The RODA modified the remedy previously selected by EPA in its 2008 Record of Decision (ROD). While the ROD required only that the radiological materials and other wastes at the site be capped, the 2018 RODA requires partial excavation of the radiological materials in addition to the previously selected capping remedy. The RODA also allows for variation in depths of excavation depending on radiological concentrations. The EPA and the PRPs have entered into a Consent Agreement to perform the Remedial Design, which is expected to be completed by early 2022. In March 2019 the PRPs received Special Notice Letters from the EPA to perform the Remedial Action work. On October 8, 2019, Cotter (Generation’s indemnitee) provided a non-binding good faith offer to conduct, or finance, a portion of the remedy, subject to certain conditions. The total estimated cost of the remedy, taking into account the current EPA technical requirements and the total costs expected to be incurred collectively by the PRPs in fully executing the remedy, is approximately $280 million, including cost escalation on an undiscounted basis, which would be allocated among the final group of PRPs. Generation has determined that a loss associated with the EPA’s partial excavation and enhanced landfill cover remedy is probable and has recorded a liability included in the table above, that reflects management’s best estimate of Cotter’s allocable share of the ultimate cost. Given the joint and several nature of this liability, the magnitude of Generation’s ultimate liability will depend on the actual costs incurred to implement the required remedy as well as on the nature and terms of any cost-sharing arrangements with the final group of PRPs. Therefore, it is reasonably possible that the ultimate cost and Cotter's associated allocable share could differ significantly once these uncertainties are resolved, which could have a material impact on Exelon's and Generation's future financial statements.

One of the other PRPs has indicated it will be making a contribution claim against Cotter for costs that it has incurred to prevent a subsurface fire from spreading to those areas of the West Lake Landfill where radiological materials are believed to have been disposed. At this time, Exelon and Generation do not possess sufficient information to assess this claim and therefore are unable to estimate a range of loss, if any. As such, no liability has been recorded for the potential contribution claim. It is reasonably possible, however, that resolution of this matter could have a material, unfavorable impact on Exelon’s and Generation's financial statements.

In January 2018, the PRPs were advised by the EPA that it will begin an additional investigation and evaluation of groundwater conditions at the West Lake Landfill. In September 2018, the PRPs agreed to an Administrative Settlement Agreement and Order on Consent for the performance by the PRPs of the groundwater Remedial

103

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 14 — Commitments and Contingencies

Investigation and Feasibility Study (RI/FS). The purpose of this RI/FS is to define the nature and extent of any groundwater contamination from the West Lake Landfill site and evaluate remedial alternatives. Generation estimates the undiscounted cost for the groundwater RI/FS to be approximately $30 million. Generation determined a loss associated with the RI/FS is probable and has recorded a liability included in the table above that reflects management’s best estimate of Cotter’s allocable share of the cost among the PRPs. At this time Generation cannot predict the likelihood or the extent to which, if any, remediation activities may be required and therefore cannot estimate a reasonably possible range of loss for response costs beyond those associated with the RI/FS component. It is reasonably possible, however, that resolution of this matter could have a material, unfavorable impact on Exelon’s and Generation’s future financial statements.

In August 2011, Cotter was notified by the DOJ that Cotter is considered a PRP with respect to the government’s clean-up costs for contamination attributable to low level radioactive residues at a former storage and reprocessing facility named Latty Avenue near St. Louis, Missouri. The Latty Avenue site is included in ComEd’s (now Generation's) indemnification responsibilities discussed above as part of the sale of Cotter. The radioactive residues had been generated initially in connection with the processing of uranium ores as part of the U.S. Government’s Manhattan Project. Cotter purchased the residues in 1969 for initial processing at the Latty Avenue facility for the subsequent extraction of uranium and metals. In 1976, the NRC found that the Latty Avenue site had radiation levels exceeding NRC criteria for decontamination of land areas. Latty Avenue was investigated and remediated by the United States Army Corps of Engineers pursuant to funding under FUSRAP. Pursuant to a series of annual agreements since 2011, the DOJ and the PRPs have tolled the statute of limitations until August 31, 2021 so that settlement discussions can proceed. On August 3, 2020, the DOJ advised Cotter and the other PRPs that it is seeking approximately $90 million from all the PRPs and has directed that the PRPs must submit a good faith joint proposed settlement offer. At this time, the DOJ has stayed their request for a good faith offer while the parties review cost documentation associated with the cost claim. Generation has determined that a loss associated with this matter is probable under its indemnification agreement with Cotter and has recorded an estimated liability, which is included in the table above.

Benning Road Site (Exelon, Generation, 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 was formerly the location of a Pepco Energy Services electric generating facility, which 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 with the DOEE, which requires Pepco and Pepco Energy Services to conduct a RI/FS for the Benning Road site and an approximately 10 to 15-acre portion of the adjacent Anacostia River.

Since 2013, Pepco and Pepco Energy Services (now Generation, pursuant to Exelon's 2016 acquisition of PHI) have been performing RI work and have submitted multiple draft RI reports to the DOEE. In September 2019, Pepco and Generation issued a draft “final” RI report which DOEE approved on February 3, 2020. Pepco and Generation 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 March 16, 2022. After completion and approval of the FS, DOEE will prepare a Proposed Plan for public comment and then issue a ROD identifying any further response actions determined to be necessary. PHI, Pepco, and Generation 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 Pepco and Generation, DOEE and the National Park Service 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 Pepco and Pepco Energy Services as part of the Benning RI/FS, as well as similar sampling efforts conducted by owners of other sites adjacent to this segment of the river and supplemental river sampling conducted by DOEE’s contractor. In April 2018, DOEE released a draft RI report for public review and comment. Pepco submitted written comments to the draft RI and participated in a public hearing.

Pepco has determined that it is probable that costs for remediation will be incurred and recorded a liability in the third quarter 2019 for management’s best estimate of its share of those costs. On September 30, 2020, DOEE released its Interim ROD. The Interim ROD reflects an adaptive management approach which will require several

104

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 14 — Commitments and Contingencies

identified “hot spots” in the river to be addressed first while continuing to conduct studies and to monitor the river to evaluate improvements and determine potential future remediation plans. The adaptive management process chosen by DOEE is less intrusive, provides more long-term environmental certainty, is less costly, and allows for site specific remediation plans already underway, including the plan for the Benning Road site to proceed to conclusion. 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 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 range of loss.

Litigation and Regulatory Matters

Asbestos Personal Injury Claims (Exelon and Generation). Generation maintains a reserve for claims associated with asbestos-related personal injury actions in certain facilities that are currently owned by Generation or were previously owned by ComEd and PECO. The estimated liabilities are recorded on an undiscounted basis and exclude the estimated legal costs associated with handling these matters, which could be material.

At March 31, 2021 and December 31, 2020, Exelon and Generation had recorded estimated liabilities of approximately $88 million and $89 million, respectively, in total for asbestos-related bodily injury claims. As of March 31, 2021, approximately $24 million of this amount related to 243 open claims presented to Generation, while the remaining $64 million is for estimated future asbestos-related bodily injury claims anticipated to arise through 2055, based on actuarial assumptions and analyses, which are updated on an annual basis. On a quarterly basis, Generation monitors actual experience against the number of forecasted claims to be received and expected claim payments and evaluates whether adjustments to the estimated liabilities are necessary.

It is reasonably possible that additional exposure to estimated future asbestos-related bodily injury claims in excess of the amount accrued could have a material, unfavorable impact on Exelon’s and Generation’s financial statements. However, management cannot reasonably estimate a range of loss beyond the amounts recorded.

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 a party to the DPA, and therefore the investigation by the USAO into Exelon’s activities ended with no charges being brought against Exelon. The SEC’s investigation remains ongoing and Exelon and ComEd have cooperated fully and intend to continue to cooperate fully with the SEC. Exelon and ComEd cannot predict the outcome of the SEC investigation. No loss contingency has been reflected in Exelon's and ComEd's consolidated financial statements with respect to the SEC investigation, as this contingency is neither probable nor reasonably estimable at this time.

105

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 14 — Commitments and Contingencies

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:

•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. Defendants' responsive pleading is due June 9, 2021.

•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. These three state cases were consolidated into a single action in October of 2020. In addition, on November 2, 2020, the Citizens Utility Board (CUB) filed a motion to intervene in the state 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, to jointly engage in mediation and have informed the court. The parties will report back to the court on the status of the mediation planning on April 29, 2021. A tentative date of June 1, 2021 has been set for oral argument on the pending motion to dismiss, but the parties have agreed to extend that date so long as a date to mediate has been selected by that time.

•Four putative class action lawsuits against ComEd and Exelon were filed in federal court in the third quarter of 2020 alleging, among other things, civil violations of federal racketeering laws. In addition, CUB filed a motion to intervene in these cases on October 22, 2020 which was granted on December 23, 2020. In addition, on December 2, 2020, the court appointed interim lead plaintiffs in the federal cases which consisted of counsel for three of the four federal cases. These plaintiffs filed a consolidated complaint on January 5, 2021. CUB also filed its own complaint against ComEd only on the same day. The remaining federal case, Potter, et al. v. Exelon et al, differed from the other lawsuits as it named additional individual defendants not named in the consolidated complaint. The Potter plaintiffs decided not to move forward with their separate lawsuit at this time and 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. Briefing on that motion was completed on March 22, 2021. As noted above, on March 25, 2021, the parties agreed, along with the state court plaintiffs, to jointly engage in mediation. The parties have notified the court of their decision to mediate. Oral argument on the pending motion to dismiss and any discovery will be stayed pending mediation.

•Five shareholders sent letters to the Exelon Board of Directors between 2020 and 2021 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.

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.

Impacts of the February 2021 Extreme Cold Weather Event and Texas-based Generating Assets Outages (Exelon and Generation). Beginning on February 15, 2021, Generation’s Texas-based generating assets within the ERCOT market, specifically Colorado Bend II, Wolf Hollow II, and Handley, experienced outages as a result of extreme cold weather conditions. In addition, those weather conditions drove increased demand for service, dramatically increased wholesale power prices, and also increased gas prices in certain regions. See Note 3 — Regulatory Matters 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 — Commitments and Contingencies

Various lawsuits have been filed against Generation during March and April of 2021 related to these events, including:

•On March 5, 2021, Generation, along with more than 160 power generators and transmission and distribution companies, was sued by approximately 160 individually named plaintiffs, purportedly on behalf of all Texans who allegedly suffered loss of life or sustained personal injury, property damage or other losses as a result of the weather events. The plaintiffs allege that the defendants failed to properly prepare for the cold weather and failed to properly conduct their operations, seeking compensatory as well as punitive damages. On April 26, 2021, another multi-plaintiff lawsuit was filed on behalf of approximately 90 plaintiffs against more than 300 defendants, including Generation, involving similar allegations of liability and claims of personal injury and property damage. During March and April of 2021, approximately 45 additional wrongful death lawsuits, naming multiple defendants including Generation, were filed by individual plaintiffs in different Texas counties, all arising out of the February weather events. Co-defendants in these lawsuits include ERCOT, transmission and distribution utilities and other generators. Generation disputes liability and denies that it is responsible for any of plaintiffs’ alleged claims and is vigorously contesting them. No loss contingencies have been reflected in Exelon’s and Generation’s consolidated financial statements with respect to these matters, as such contingencies are neither probable nor reasonably estimable at this time.

•On March 22, 2021, a LDC filed a lawsuit in Missouri federal court against Generation for breach of contract and unjust enrichment, seeking damages of approximately $40 million. The plaintiff claims that Generation failed to deliver gas to its customers in February of 2021, causing the plaintiff to incur damages by forcing it to purchase gas for Generation’s customers and by Generation’s refusal to pay the resulting penalties. On March 26, 2021, Generation filed a complaint with the MPSC against the LDC to void the OFO penalties, or alternatively to grant a waiver or variance from the tariff requirements, to prohibit the LDC from billing or otherwise attempting to collect from Generation or any Missouri customer any portion of the penalties claimed by the LDC until the resolution of the complaint, and to prohibit the LDC from taking any retaliatory measure, including termination of service. Generation has requested expedited treatment, but there is no timeline by which the MPSC must act. Based on the penalty provisions within the tariff that was in effect at the relevant time, Exelon and Generation recorded a liability of approximately $40 million as of March 31, 2021.

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.

15. Changes in Accumulated Other Comprehensive Income (Exelon)

The following tables present changes in Exelon's AOCI, net of tax, by component:

Three Months Ended March 31, 2021	Losses on Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items (a)		Foreign Currency Items		Total
Beginning balance	$	(5)	$	(3,372)	$	(23)	$	(3,400)
OCI before reclassifications	—		(2)		1		(1)
Amounts reclassified from AOCI	—		55		—		55
Net current-period OCI	—		53		1		54
Ending balance	$	(5)	$	(3,319)	$	(22)	$	(3,346)

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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 15 — Changes in Accumulated Other Comprehensive Income

Three Months Ended March 31, 2020	Losses on Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items (a)		Foreign Currency Items		Total
Beginning balance	$	(2)	$	(3,165)	$	(27)	$	(3,194)
OCI before reclassifications	(1)		(7)		(8)		(16)
Amounts reclassified from AOCI	—		37		—		37
Net current-period OCI	(1)		30		(8)		21
Ending balance	$	(3)	$	(3,135)	$	(35)	$	(3,173)

_________

(a)AOCI amounts are included in the computation of net periodic pension and OPEB cost. See Note 10 — Retirement Benefits for additional information. See Exelon's Statements of Operations and Comprehensive Income for individual components of AOCI.

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

	Three Months Ended March 31,
	2021		2020
Pension and non-pension postretirement benefit plans:
Prior service benefit reclassified to periodic benefit cost	$	1	$	4
Actuarial loss reclassified to periodic benefit cost	(19)		(17)
Pension and non-pension postretirement benefit plans valuation adjustment	—		3

16. Variable Interest Entities (Exelon, Generation, PHI and ACE)

At March 31, 2021 and December 31, 2020, Exelon, Generation, PHI, and ACE collectively consolidated several VIEs or VIE groups for which the applicable Registrant was the primary beneficiary (see Consolidated VIEs below) and had significant interests in several other VIEs for which the applicable Registrant does not have the power to direct the entities’ activities and, accordingly, was not the primary beneficiary (see Unconsolidated VIEs below). Consolidated and unconsolidated VIEs are aggregated to the extent that the entities have similar risk profiles.

Consolidated VIEs

The table below shows the carrying amounts and classification of the consolidated VIEs’ assets and liabilities included in the consolidated financial statements of Exelon, Generation, PHI, and ACE as of March 31, 2021 and December 31, 2020. The assets, except as noted in the footnotes to the table below, can only be used to settle obligations of the VIEs. The liabilities, except as noted in the footnote to the table below, are such that creditors, or beneficiaries, do not have recourse to the general credit of Exelon, Generation, PHI, and ACE.

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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 16 — Variable Interest Entities

	March 31, 2021								December 31, 2020
	Exelon		Generation		PHI (a)		ACE		Exelon		Generation		PHI (a)		ACE
Cash and cash equivalents	$	175	$	175	$	—	$	—	$	98	$	98	$	—	$	—
Restricted cash and cash equivalents	37		33		4		4		47		44		3		3
Accounts receivable
Customer	145		145		—		—		148		148		—		—
Other	35		35		—		—		36		36		—		—
Unamortized energy contract assets	22		22		—		—		22		22		—		—
Inventories, net
Materials and supplies	242		242		—		—		244		244		—		—
Assets held for sale(b)	—		—		—		—		101		101		—		—
Other current assets	448		443		5		—		674		669		5		—
Total current assets	1,104		1,095		9		4		1,370		1,362		8		3
Property, plant, and equipment, net	5,747		5,747		—		—		5,803		5,803		—		—
Nuclear decommissioning trust funds	3,089		3,089		—		—		3,007		3,007		—		—
Unamortized energy contract assets	243		243		—		—		249		249		—		—
Other noncurrent assets	47		38		9		9		52		42		10		10
Total noncurrent assets	9,126		9,117		9		9		9,111		9,101		10		10
Total assets(c)	$	10,230	$	10,212	$	18	$	13	$	10,481	$	10,463	$	18	$	13
Long-term debt due within one year	$	90	$	69	$	21	$	16	$	94	$	68	$	26	$	21
Accounts payable	95		95		—		—		81		81		—		—
Accrued expenses	67		67		—		—		70		70		—		—
Unamortized energy contract liabilities	3		3		—		—		4		4		—		—
Liabilities held for sale(b)	—		—		—		—		16		16		—		—
Other current liabilities	1		1		—		—		5		5		—		—
Total current liabilities	256		235		21		16		270		244		26		21
Long-term debt	861		861		—		—		889		889		—		—
Asset retirement obligations	2,347		2,347		—		—		2,318		2,318		—		—
Other noncurrent liabilities	116		116		—		—		129		129		—		—
Total noncurrent liabilities	3,324		3,324		—		—		3,336		3,336		—		—
Total liabilities(d)	$	3,580	$	3,559	$	21	$	16	$	3,606	$	3,580	$	26	$	21

_________

(a)Includes certain purchase accounting adjustments from the PHI merger not pushed down to ACE.

(b)In the fourth quarter of 2020, Generation entered into an agreement for the sale of a significant portion of Generation's solar business, and as a result of this transaction, Exelon and Generation reclassified the consolidated VIEs' solar assets and liabilities as held for sale. Completion of the transaction occurred in the first quarter of 2021. Refer to Note 2 - Mergers, Acquisitions, and Dispositions for additional information on the solar business.

(c)Exelon’s and Generation’s balances include unrestricted assets for current unamortized energy contract assets of $22 million and $22 million, non-current unamortized energy contract assets of $222 million and $249 million, Assets held for sale of $0 million and $9 million, and other unrestricted assets of $1 million and $1 million as of March 31, 2021 and December 31, 2020, respectively

(d)Exelon’s and Generation’s balances include liabilities with recourse of $2 million and $8 million as of March 31, 2021 and December 31, 2020, respectively.

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COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 16 — Variable Interest Entities

As of March 31, 2021 and December 31, 2020, Exelon's and Generation's consolidated VIEs consist of:

Consolidated VIE or VIE groups:	Reason entity is a VIE:	Reason Generation is primary beneficiary:
CENG - A joint venture between Generation and EDF. Generation has a 50.01% equity ownership in CENG. See additional discussion below.	Disproportionate relationship between equity interest and operational control as a result of the NOSA described further below.	Generation conducts the operational activities.
EGRP - A collection of wind and solar project entities. Generation has a 51% equity ownership in EGRP. See additional discussion below.	Similar structure to a limited partnership and the limited partners do not have kick out rights with respect to the general partner.	Generation conducts the operational activities.
Bluestem Wind Energy Holdings, LLC - A Tax Equity structure which is consolidated by EGRP. Generation has a noncontrolling interest.	Similar structure to a limited partnership and the limited partners do not have kick out rights with respect to the general partner.	Generation conducts the operational activities.
Antelope Valley - A solar generating facility, which is 100% owned by Generation. Antelope Valley sells all of its output to PG&E through a PPA.	The PPA contract absorbs variability through a performance guarantee.	Generation conducts all activities.
Equity investment in distributed energy company - Generation has a 31% equity ownership. This distributed energy company has an interest in an unconsolidated VIE. (See Unconsolidated VIEs disclosure below). Generation fully impaired this investment in 2019.	Similar structure to a limited partnership and the limited partners do not have kick out rights with respect to the general partner.	Generation conducts the operational activities.
NER - A bankruptcy remote, special purpose entity which is 100% owned by Generation, which purchases certain of Generation’s customer accounts receivable arising from the sale of retail electricity. NER’s assets will be available first and foremost to satisfy the claims of the creditors of NER. See Note 6 - Accounts Receivable for additional information on the sale of receivables.	Equity capitalization is insufficient to support its operations.	Generation conducts all activities.

CENG - On April 1, 2014, Generation, CENG, and subsidiaries of CENG executed the NOSA pursuant to which Generation conducts all activities associated with the operations of the CENG fleet and provides corporate and administrative services to CENG and the CENG fleet for the remaining life of the CENG nuclear plants as if they were a part of the Generation nuclear fleet, subject to the CENG member rights of EDF.

EDF has the option to sell its 49.99% equity interest in CENG to Generation. On November 20, 2019, Generation received notice of EDF's intention to exercise the put option to sell its interest in CENG to Generation and the put automatically exercised on January 19, 2020. Refer to Note 2 - Mergers, Acquisitions, and Dispositions for additional information.

Exelon and Generation, where indicated, provide the following support to CENG:

•Generation executed an Indemnity Agreement pursuant to which Generation agreed to indemnify EDF against third-party claims that may arise from any future nuclear incident (as defined in the Price-Anderson Act) in connection with the CENG nuclear plants or their operations. Exelon guarantees Generation’s obligations under this Indemnity Agreement. See Note 19 — Commitments and Contingencies of the Exelon 2020 Form 10-K for more details,

•Generation and EDF share in the $688 million of contingent payment obligations for the payment of contingent retrospective premium adjustments for the nuclear liability insurance, and

•Exelon has executed an agreement to provide up to $245 million to support the operations of CENG as well as a $165 million guarantee of CENG’s cash pooling agreement with its subsidiaries.

EGRP - EGRP is a collection of wind and solar project entities and some of these project entities are VIEs that are consolidated by EGRP. Generation owns a number of limited liability companies that build, own, and operate solar and wind power facilities some of which are owned by EGRP. While Generation or EGRP owns 100% of the solar entities and 100% of the majority of the wind entities, it has been determined that certain of the solar and

110

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 16 — Variable Interest Entities

wind entities are VIEs because the entities require additional subordinated financial support in the form of a parental guarantee of debt, loans from the customers in order to obtain the necessary funds for construction of the solar facilities, or the customers absorb price variability from the entities through the fixed price power and/or REC purchase agreements. Generation is the primary beneficiary of these solar and wind entities that qualify as VIEs because Generation controls the design, construction, and operation of the facilities. There is limited recourse to Generation related to certain solar and wind entities.

In 2017, Generation’s interests in EGRP were contributed to and are pledged for the ExGen Renewables IV non-recourse debt project financing structure. Refer to Note 17 — Debt and Credit Agreements of the Exelon 2020 Form 10-K for additional information on ExGen Renewables IV.

As of March 31, 2021 and December 31, 2020, Exelon's, PHI's and ACE's consolidated VIE consists of:

Consolidated VIEs:	Reason entity is a VIE:	Reason ACE is the primary beneficiary:
ACE Funding - A special purpose entity formed by ACE for the purpose of securitizing authorized portions of ACE’s recoverable stranded costs through the issuance and sale of Transition Bonds. Proceeds from the sale of each series of Transition Bonds by ATF were transferred to ACE in exchange for the transfer by ACE to ATF of the right to collect a non-bypassable Transition Bond Charge from ACE customers pursuant to bondable stranded costs rate orders issued by the NJBPU in an amount sufficient to fund the principal and interest payments on Transition Bonds and related taxes, expenses and fees.	ACE’s equity investment is a variable interest as, by design, it absorbs any initial variability of ATF. The bondholders also have a variable interest for the investment made to purchase the Transition Bonds.	ACE controls the servicing activities.

Unconsolidated VIEs

Exelon’s and Generation’s variable interests in unconsolidated VIEs generally include equity investments and energy purchase and sale contracts. For the equity investments, the carrying amount of the investments is reflected in Exelon’s and Generation’s Consolidated Balance Sheets in Investments. For the energy purchase and sale contracts (commercial agreements), the carrying amount of assets and liabilities in Exelon’s and Generation’s Consolidated Balance Sheets that relate to their involvement with the VIEs are predominately related to working capital accounts and generally represent the amounts owed by, or owed to, Exelon and Generation for the deliveries associated with the current billing cycles under the commercial agreements.

As of March 31, 2021 and December 31, 2020, Exelon and Generation had significant unconsolidated variable interests in several VIEs for which Exelon or Generation, as applicable, was not the primary beneficiary. These interests include certain equity method investments and certain commercial agreements.

The following table presents summary information about Exelon's and Generation’s significant unconsolidated VIE entities:

	March 31, 2021						December 31, 2020
	Commercial Agreement VIEs		Equity Investment VIEs		Total		Commercial Agreement VIEs		Equity Investment VIEs		Total
Total assets(a)	$	789	$	386	$	1,175	$	777	$	401	$	1,178
Total liabilities(a)	95		218		313		61		223		284
Exelon's ownership interest in VIE(a)	—		150		150		—		157		157
Other ownership interests in VIE(a)	694		18		712		716		21		737

_________

(a)These items represent amounts on the unconsolidated VIE balance sheets, not in Exelon’s or Generation’s Consolidated Balance Sheets. These items are included to provide information regarding the relative size of the unconsolidated VIEs. Exelon and Generation do not have any exposure to loss as they do not have a carrying amount in the equity investment VIEs as of March 31, 2021 and December 31, 2020.

111

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 16 — Variable Interest Entities

As of March 31, 2021 and December 31, 2020, Exelon's and Generation's unconsolidated VIEs consist of:

Unconsolidated VIE groups:	Reason entity is a VIE:	Reason Generation is not the primary beneficiary:
Equity investments in distributed energy companies - 1) Generation has a 90% equity ownership in a distributed energy company. 2) Generation, via a consolidated VIE, has a 90% equity ownership in another distributed energy company (See Consolidated VIEs disclosure above). Generation fully impaired this investment in 2019.	Similar structures to a limited partnership and the limited partners do not have kick out rights with respect to the general partner.	Generation does not conduct the operational activities.
Energy Purchase and Sale agreements - Generation has several energy purchase and sale agreements with generating facilities.	PPA contracts that absorb variability through fixed pricing.	Generation does not conduct the operational activities.

17. 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.

	Operating revenues
	Exelon		Generation		PHI		DPL
Three Months Ended March 31, 2021
Operating lease income	$	4	$	3	$	1	$	1
Variable lease income	64		64		—		—
Three Months Ended March 31, 2020
Operating lease income	$	5	$	3	$	1	$	1
Variable lease income	69		69		—		—

	Taxes other than income taxes
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Utility taxes(a)	$	217	$	24	$	59	$	35	$	25	$	74	$	67	$	6	$	1
Property	154		68		8		4		42		32		21		10		1
Payroll	61		28		7		4		5		7		2		1		—
Three Months Ended March 31, 2020
Utility taxes(a)	$	218	$	26	$	60	$	31	$	26	$	75	$	69	$	6	$	—
Property	150		69		7		4		39		31		21		9		1
Payroll	63		31		7		4		4		8		2		1		1

__________

(a)Generation’s utility tax represents gross receipts tax related to its retail operations, and the Utility Registrants' utility taxes represents 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.

112

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 17 — Supplemental Financial Information

	Other, net
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Decommissioning-related activities:
Net realized income on NDT funds(a)
Regulatory Agreement Units	$	291	$	291	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Non-Regulatory Agreement Units	203		203		—		—		—		—		—		—		—
Net unrealized gains on NDT funds
Regulatory Agreement Units	(82)		(82)		—		—		—		—		—		—		—
Non-Regulatory Agreement Units	(66)		(66)		—		—		—		—		—		—		—
Regulatory offset to NDT fund-related activities(b)	(167)		(167)		—		—		—		—		—		—		—
Decommissioning-related activities	179		179		—		—		—		—		—		—		—
AFUDC — Equity	28		—		4		6		7		11		9		1		1
Non-service net periodic benefit cost	20		—		—		—		—		—		—		—		—
Three Months Ended March 31, 2020
Decommissioning-related activities:
Net realized income on NDT funds(a)
Regulatory Agreement Units	$	47	$	47	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Non-Regulatory Agreement Units	82		82		—		—		—		—		—		—		—
Net unrealized gains on NDT funds
Regulatory Agreement Units	(932)		(932)		—		—		—		—		—		—		—
Non-Regulatory Agreement Units	(706)		(706)		—		—		—		—		—		—		—
Regulatory offset to NDT fund-related activities(b)	709		709		—		—		—		—		—		—		—
Decommissioning-related activities	(800)		(800)		—		—		—		—		—		—		—
AFUDC — Equity	23		—		6		3		5		9		6		1		2
Non-service net periodic benefit cost	10		—		—		—		—		—		—		—		—

__________

(a)Realized income includes interest, dividends and realized gains and losses on sales of NDT fund investments.

(b)Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of income taxes related to all NDT fund activity for those units. See Note 10 — Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information regarding the accounting for nuclear decommissioning.

113

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 17 — Supplemental Financial Information

Supplemental Cash Flow Information

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

	Depreciation, amortization and accretion
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Property, plant, and equipment(a)	$	1,522	$	928	$	239	$	82	$	106	$	154	$	67	$	42	$	37
Amortization of regulatory assets(a)	160		—		53		4		46		56		35		11		10
Amortization of intangible assets, net(a)	15		12		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(b)	4		3		—		—		—		—		—		—		—
Nuclear fuel(c)	276		276		—		—		—		—		—		—		—
ARO accretion(d)	127		127		—		—		—		—		—		—		—
Total depreciation, amortization and accretion	$	2,104	$	1,346	$	292	$	86	$	152	$	210	$	102	$	53	$	47
Three Months Ended March 31, 2020
Property, plant, and equipment(a)	$	856	$	290	$	228	$	79	$	97	$	144	$	64	$	38	$	34
Amortization of regulatory assets(a)	149		—		45		7		46		50		31		10		9
Amortization of intangible assets, net(a)	16		14		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(b)	2		2		—		—		—		—		—		—		—
Nuclear fuel(c)	231		231		—		—		—		—		—		—		—
ARO accretion(d)	124		124		—		—		—		—		—		—		—
Total depreciation, amortization and accretion	$	1,378	$	661	$	273	$	86	$	143	$	194	$	95	$	48	$	43

__________

(a)Included in Depreciation and amortization in the Registrants' Consolidated Statements of Operations and Comprehensive Income.

(b)Included in Operating revenues or Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

(c)Included in Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

(d)Included in Operating and maintenance expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

114

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 17 — Supplemental Financial Information

	Other non-cash operating activities
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Pension and non-pension postretirement benefit costs	$	95	$	26	$	32	$	2	$	14	$	12	$	2	$	1	$	3
Allowance for credit losses	85		34		13		24		4		10		5		4		1
Other decommissioning-related activity(a)	(322)		(332)		—		—		—		—		—		—		—
Energy-related options(b)	17		17		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(c)	(129)		—		(54)		(10)		(18)		(46)		(26)		(9)		(11)
Long-term incentive plan	32		—		—		—		—		—		—		—		—
Amortization of operating ROU asset	37		21		—		—		7		7		1		3		1
AFUDC - Equity	(28)		—		(4)		(6)		(7)		(11)		(9)		(1)		(1)
Three Months Ended March 31, 2020
Pension and non-pension postretirement benefit costs	$	98	$	27	$	28	$	1	$	15	$	17	$	3	$	1	$	3
Allowance for credit losses	45		4		7		17		7		10		4		3		3
Other decommissioning-related activity(a)	128		128		—		—		—		—		—		—		—
Energy-related options(b)	6		6		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(d)	(71)		—		(17)		—		(35)		(19)		(15)		(4)		—
Long-term incentive plan	(7)		—		—		—		—		—		—		—		—
Amortization of operating ROU asset	51		35		—		—		8		5		2		2		1
AFUDC - Equity	(23)		—		(6)		(3)		(5)		(9)		(6)		(1)		(2)

__________

(a)Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income, and income taxes related to all NDT fund activity for these units. See Note 10 — Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information regarding the accounting for nuclear decommissioning.

(b)Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations.

(c)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, and DPL, reflects the change in regulatory assets and liabilities associated with their decoupling mechanisms and transmission formula rates. For PECO and ACE, reflects the change in regulatory assets and liabilities associated with their transmission formula rates. See Note 3 — Regulatory Matters for additional information.

(d)For ComEd, reflects the true-up adjustments in regulatory assets and liabilities associated with its distribution and energy efficiency formula rates. For BGE, Pepco, and DPL, reflects the change in regulatory assets and liabilities associated with their decoupling mechanisms. See Note 3 — Regulatory Matters for additional information.

115

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 17 — 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		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2021
Cash and cash equivalents	$	1,908	$	721	$	86	$	48	$	21	$	558	$	134	$	64	$	353
Restricted cash and cash equivalents	374		41		270		7		1		37		33		—		4
Restricted cash included in other long-term assets	52		—		43		—		—		9		—		—		9
Total cash, restricted cash, and cash equivalents	$	2,334	$	762	$	399	$	55	$	22	$	604	$	167	$	64	$	366
December 31, 2020
Cash and cash equivalents	$	663	$	226	$	83	$	19	$	144	$	111	$	30	$	15	$	17
Restricted cash and cash equivalents	438		89		279		7		1		39		35		—		3
Restricted cash included in other long-term assets	53		—		43		—		—		10		—		—		10
Cash, restricted cash, and cash equivalents - Held for Sale	12		12		—		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents	$	1,166	$	327	$	405	$	26	$	145	$	160	$	65	$	15	$	30
March 31, 2020
Cash and cash equivalents	$	1,457	$	821	$	514	$	31	$	11	$	49	$	18	$	7	$	8
Restricted cash and cash equivalents	414		150		211		7		1		37		33		—		3
Restricted cash included in other long-term assets	121		—		108		—		—		12		—		—		12
Total cash, restricted cash, and cash equivalents	$	1,992	$	971	$	833	$	38	$	12	$	98	$	51	$	7	$	23
December 31, 2019
Cash and cash equivalents	$	587	$	303	$	90	$	21	$	24	$	131	$	30	$	13	$	12
Restricted cash and cash equivalents	358		146		150		6		1		36		33		—		2
Restricted cash included in other long-term assets	177		—		163		—		—		14		—		—		14
Total cash, restricted cash, and cash equivalents	$	1,122	$	449	$	403	$	27	$	25	$	181	$	63	$	13	$	28

For additional information on restricted cash see Note 1 — Significant Accounting Policies of the Exelon 2020 Form 10-K.

116

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 17 — Supplemental Financial Information

Supplemental Balance Sheet Information

The following tables provide additional information about material items recorded in the Registrants' Consolidated Balance Sheets.

	Accrued expenses
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2021
Compensation-related accruals(a)	$	581	$	210	$	91	$	42	$	49	$	73	$	26	$	15	$	12
Taxes accrued	540		279		70		18		50		108		92		10		12
Interest accrued	424		76		65		36		41		79		37		20		20
December 31, 2020
Compensation-related accruals(a)	$	1,069	$	426	$	170	$	73	$	84	$	109	$	36	$	18	$	17
Taxes accrued	527		229		94		16		73		117		90		18		12
Interest accrued	331		44		109		37		46		51		26		7		12

__________

(a)Primarily includes accrued payroll, bonuses and other incentives, vacation and benefits.

18. Related Party Transactions (All Registrants)

Operating revenues from affiliates

Generation

The following table presents Generation’s Operating revenues from affiliates, which are primarily recorded as Purchased power from affiliates and an immaterial amount recorded as Operating and maintenance expense from affiliates at the Utility Registrants:

	Three Months Ended March 31,
	2021		2020
Operating revenues from affiliates:
ComEd(a)(b)	$	78	$	90
PECO(c)	42		37
BGE(d)	72		99
PHI	100		103
Pepco(e)	75		79
DPL(f)	21		22
ACE(g)	4		2
Other	3		1
Total operating revenues from affiliates (Generation)	$	295	$	330

__________

(a)Generation has an ICC-approved RFP contract with ComEd to provide a portion of ComEd’s electricity supply requirements. Generation also sells RECs and ZECs to ComEd.

(b)For the three months ended March 31, 2021, ComEd’s Purchased power from Generation of $84 million is recorded as Operating revenues from ComEd of $78 million and as Purchased power and fuel from ComEd of $6 million at Generation. For the three months ended March 31, 2020, ComEd’s Purchased power from Generation of $97 million is recorded as Operating revenues from ComEd of $90 million and as Purchased power and fuel from ComEd of $7 million at Generation.

(c)Generation provides electric supply to PECO under contracts executed through PECO’s competitive procurement process. In addition, Generation has a ten-year agreement with PECO to sell solar AECs.

(d)Generation provides a portion of BGE’s energy requirements under its MDPSC-approved market-based SOS and gas commodity programs.

117

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 18 — Related Party Transactions

(e)Generation provides electric supply to Pepco under contracts executed through Pepco's competitive procurement process approved by the MDPSC and DCPSC.

(f)Generation provides a portion of DPL's energy requirements under its MDPSC and DPSC-approved market-based SOS commodity programs.

(g)Generation provides electric supply to ACE under contracts executed through ACE's competitive procurement process.

PHI

PHI’s Operating revenues from affiliates are primarily with BSC for services that PHISCO provides to BSC.

Operating and maintenance expense from affiliates

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 March 31,				Three Months Ended March 31,
	2021		2020		2021		2020
Exelon
BSC					$	124	$	113
PHISCO					17		14
Generation
BSC	$	144	$	140	10		11
ComEd
BSC	71		72		45		42
PECO
BSC	39		37		17		16
BGE
BSC	43		41		20		28
PHI
BSC	39		37		32		16
PHISCO	—		—		17		14
Pepco
BSC	22		21		13		6
PHISCO	30		30		7		6
DPL
BSC	14		13		10		5
PHISCO	25		24		5		4
ACE
BSC	12		11		8		4
PHISCO	22		22		5		4

118

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 18 — Related Party Transactions

Current Receivables from/Payables to affiliates

The following tables present current receivables from affiliates and current payables to affiliates:

March 31, 2021

	Receivables from affiliates:
Payables to affiliates:	Generation			ComEd		PECO		BGE		Pepco		DPL		ACE		BSC		PHISCO		Other		Total
Generation				$	17	$	—	$	—	$	—	$	—	$	—	$	84	$	—	$	24	$	125
ComEd	$	50	(a)			—		—		—		—		—		49		—		5		104
PECO	15			—				—		—		—		—		24		—		7		46
BGE	11			1		—				—		—		—		30		—		1		43
PHI	—			1		—		—		—		—		—		7		—		10		18
Pepco	12			1		—		—				—		—		16		14		1		44
DPL	2			—		—		—		—				—		11		11		—		24
ACE	8			—		—		—		—		—				8		10		1		27
Other	8			1		—		—		—		—		1		—		—				10
Total	$	106		$	21	$	—	$	—	$	—	$	—	$	1	$	229	$	35	$	49	$	441

December 31, 2020

	Receivables from affiliates:
Payables to affiliates:	Generation			ComEd		PECO		BGE		Pepco		DPL		ACE		BSC		PHISCO		Other		Total
Generation				$	13	$	—	$	—	$	—	$	—	$	—	$	72	$	—	$	22	$	107
ComEd	$	78	(a)			—		—		—		—		—		59		—		9		146
PECO	17			1				—		—		—		—		28		—		4		50
BGE	11			—		—				—		—		—		47		—		3		61
PHI	—			—		—		—		—		—		—		4		—		11		15
Pepco	13			2		—		1				—		—		25		14		—		55
DPL	3			1		—		—		—				—		21		10		1		36
ACE	6			—		—		—		—		—				15		9		1		31
Other	25			5		2		2		2		1		6		—		—				43
Total	$	153		$	22	$	2	$	3	$	2	$	1	$	6	$	271	$	33	$	51	$	544

__________

(a)As of March 31, 2021 and December 31, 2020, Generation had a contract liability with ComEd for $24 million and $50 million, respectively, that was included in Other current liabilities on Generation’s Consolidated Balance Sheets. At March 31, 2021 and December 31, 2020, ComEd had a Current Payable to Generation of $26 million and $28 million, respectively, on its Consolidated Balance Sheets, which consisted of Generation’s Current Receivable from ComEd, partially offset by Generation’s contract liability with ComEd.

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. Generation, 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/Payables to affiliates

Generation has long-term payables to ComEd and PECO as a result of the nuclear decommissioning contractual construct whereby, to the extent NDT funds are greater than the underlying ARO at the end of decommissioning, such amounts are due back to ComEd and PECO, as applicable, for payment to their respective customers. See Note 10 — Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information.

119

COMBINED NOTES TO CONSOLIDATED FINANCIAL STATEMENTS — (Continued)

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

Note 18 — Related Party Transactions

The following table presents noncurrent receivables from affiliates at ComEd and PECO which are recorded as noncurrent payables to affiliates at Generation:

	March 31, 2021		December 31, 2020
ComEd	$	2,375	$	2,541
PECO	490		475

Long-term debt to financing trusts

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

	March 31, 2021						December 31, 2020
	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

Long-term debt to affiliates

In connection with the debt obligations assumed by Exelon as part of the Constellation merger, Exelon and subsidiaries of Generation (former Constellation subsidiaries) assumed intercompany loan agreements that mirror the terms and amounts of the third-party debt obligations of Exelon, resulting in intercompany notes payable included in Long-term debt to affiliates in Generation’s Consolidated Balance Sheets and intercompany notes receivable at Exelon Corporate.

19. Planned 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. Under the separation plan, Exelon shareholders will retain their current shares of Exelon stock and receive a pro-rata distribution of shares of the new company’s stock in a transaction that is expected to be tax-free to Exelon and its shareholders for U.S. federal income tax purposes. The actual number of shares to be distributed to Exelon shareholders will be determined prior to closing.

Exelon is targeting to complete the separation in the first quarter of 2022, subject to final approval by Exelon’s Board of Directors, a Form 10 registration statement being declared effective by the SEC, regulatory approvals, and satisfaction of other conditions. The transaction is subject to approval by the FERC, NRC, and NYPSC and receipt of a private letter ruling from the IRS and tax opinion from Exelon’s tax advisors.

On February 25, 2021, Exelon and Generation filed applications with the FERC, NYPSC, and NRC seeking approvals for the separation of Generation. On March 25, 2021, Exelon filed a request for a private letter ruling with the IRS to confirm the tax-free treatment of the planned separation. Exelon and Generation expect a decision from the FERC and the IRS in the third quarter of 2021, the NRC in the fourth quarter of 2021, and have requested a decision from the NYPSC before the end of 2021 but cannot predict if the applications will be approved as filed.

There can be no assurance that any separation transaction will ultimately occur or, if one does occur, of its terms or timing.

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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 generation, delivery, and marketing of energy through Generation and the energy distribution and transmission businesses through ComEd, PECO, BGE, Pepco, DPL, and ACE.

Exelon has eleven reportable segments consisting of Generation’s five reportable segments (Mid-Atlantic, Midwest, New York, ERCOT, and Other Power Regions), 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 eight separate operating subsidiary registrants, Generation, 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, Generation, 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 (Loss) attributable to common shareholders by Registrant for the three months ended March 31, 2021 compared to the same period in 2020. For additional information regarding the financial results for the three months ended March 31, 2021 and 2020 see the discussions of Results of Operations by Registrant.

	Three Months Ended March 31,				Favorable (unfavorable) variance
	2021		2020
Exelon	$	(289)	$	582	$	(871)
Generation	(793)		45		(838)
ComEd	197		168		29
PECO	167		140		27
BGE	209		181		28
PHI	128		108		20
Pepco	59		52		7
DPL	56		45		11
ACE	14		13		1
Other(a)	(197)		(60)		(137)

__________

(a)Primarily includes eliminating and consolidating adjustments, Exelon’s corporate operations, shared service entities and other financing and investing activities.

Three Months Ended March 31, 2021 Compared to Three Months Ended March 31, 2020. Net income attributable to common shareholders decreased by $871 million and diluted loss per average common share decreased to $(0.30) in 2021 from $0.60 in 2020 primarily due to:

•Impacts of the February 2021 extreme cold weather event;

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•Accelerated depreciation and amortization associated with Generation's decisions in the third quarter of 2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024; and

•The absence of a prior year one-time tax settlement.

The decreases were partially offset by:

•Lower unrealized losses and higher realized gains on NDT funds;

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

•The favorable impacts of the multi-year plan at BGE and regulatory rate increases at DPL; and

•Favorable weather conditions at PECO, DPL and ACE.

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 compensation targets, and planning and forecasting of future periods. Adjusted (non-GAAP) operating earnings is not a presentation defined under GAAP and may not be comparable to other companies’ presentations or deemed more useful than the GAAP information provided elsewhere in this report.

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The following table provides a reconciliation between net income (loss) attributable to common shareholders as determined in accordance with GAAP and adjusted (non-GAAP) operating earnings (loss) for the three months ended March 31, 2021 compared to the same period in 2020.

	Three Months Ended March 31,
	2021				2020
(In millions, except per share data)			Earnings per Diluted Share				Earnings per Diluted Share
Net Income (Loss) Attributable to Common Shareholders	$	(289)	$	(0.30)	$	582	$	0.60
Mark-to-Market Impact of Economic Hedging Activities (net of taxes of $46 and $32, respectively)	(135)		(0.14)		(94)		(0.10)
Unrealized Losses Related to NDT Fund Investments (net of taxes of $40 and $405, respectively)(a)	43		0.04		485		0.50
Asset Impairments (net of taxes of $1)	—		—		2		—
Plant Retirements and Divestitures (net of taxes of $103 and $4, respectively)(b)	310		0.32		13		0.01
Cost Management Program (net of taxes of $0 and $3, respectively)(c)	1		—		9		0.01
Change in Environmental Liabilities (net of taxes of $1)	2		—		—		—
COVID-19 Direct Costs (net of taxes of $4)(d)	10		0.01		—		—
Acquisition Related Costs (net of tax of $2)(e)	6		0.01		—		—
ERP System Implementation Costs (net of taxes of $1)(f)	5		0.01		—		—
Planned Separation Costs (net of taxes of $2)(g)	7		0.01		—		—
Income Tax-Related Adjustments (entire amount represents tax expense)	(2)		—		(2)		—
Noncontrolling Interests (net of taxes of $6 and $30, respectively)(h)	(17)		(0.02)		(144)		(0.15)
Adjusted (non-GAAP) Operating Earnings (Loss)	$	(60)	$	(0.06)	$	851	$	0.87

__________

Note:

Amounts may not sum due to rounding.

Unless otherwise noted, the income tax impact of each reconciling item between GAAP Net Income (Loss) and Adjusted (non-GAAP) Operating Earnings (Loss) 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. For all items except the unrealized losses related to NDT fund investments, the marginal statutory income tax rates for 2021 and 2020 ranged from 25.0% to 29.0%. Under IRS regulations, NDT fund investment returns are taxed at different rates for investments if they are in qualified or non-qualified funds. The effective tax rates for the unrealized losses related to NDT fund investments were 48.0% and 45.5% for the three months ended March 31, 2021 and 2020, respectively.

(a)Reflects the impact of net unrealized losses on Generation’s NDT fund investments for Non-Regulatory and Regulatory Agreement Units. The impacts of the Regulatory Agreement Units, including the associated income taxes, are contractually eliminated, resulting in no earnings impact.

(b)In 2021, primarily reflects accelerated depreciation and amortization associated with Generation's decision in the third quarter of 2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024, partially offset by a gain on sale of Generation's solar business. In 2020, primarily reflects accelerated depreciation and amortization expenses associated with the early retirement of certain fossil sites.

(c)Primarily represents reorganization costs related to cost management programs.

(d)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.

(e)Reflects costs related to the acquisition of EDF's interest in CENG.

(f)Reflects costs related to a multi-year Enterprise Resource Program (ERP) system implementation.

(g)Represents costs related to the planned separation primarily comprised of third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation as well as employee-related severance costs.

(h)Represents elimination from Generation’s results of the noncontrolling interests related to certain exclusion items, primarily related to unrealized gains and losses on NDT fund investments for CENG units.

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Significant 2021 Transactions and Developments

Planned 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 with the resources necessary to best serve customers and sustain long-term investment and operating excellence. The separation gives each company the financial and strategic independence to focus on its specific customer needs, while executing its core business strategy.

On February 25, 2021, Exelon and Generation filed applications with the FERC, NYPSC, and NRC seeking approvals for the separation of Generation. On March 25, 2021, Exelon filed a request for a private letter ruling with the IRS to confirm the tax-free treatment of the planned separation. Exelon and Generation expect a decision from the FERC and the IRS in the third quarter of 2021, the NRC in the fourth quarter of 2021, and have requested a decision from the NYPSC before the end of 2021 but cannot predict if the applications will be approved as filed.

In connection with the planned separation, Exelon incurred transaction costs of approximately $9 million on a pre-tax basis in the first quarter of 2021, which are excluded from Adjusted (non-GAAP) Operating Earnings. The transaction costs are primarily comprised of third-party costs paid to advisors, consultants, lawyers, and other experts assisting in the planned separation as well as employee-related severance costs.

There can be no assurance that any separation transaction will ultimately occur or, if one does occur, of its terms or timing. See Note 19 — Planned Separation of the Combined Notes to Consolidated Financial Statements for additional information.

Impacts of the February 2021 Extreme Cold Weather Event and Texas-based Generating Assets Outages

Beginning on February 15, 2021, Generation’s Texas-based generating assets within the ERCOT market, specifically Colorado Bend II, Wolf Hollow II, and Handley, experienced outages as a result of extreme cold weather conditions. In addition, those weather conditions drove increased demand for service, dramatically increased wholesale power prices, and also increased gas prices in certain regions.

The estimated impact to Exelon’s and Generation’s Net income for the first quarter of 2021 arising from these market and weather conditions was a reduction of approximately $880 million. The first quarter estimated impact includes certain charges associated with the natural gas business that may be reduced through waivers and/or recoveries from customers. Therefore, such charges are not included in the estimated full year earnings impact. Exelon and Generation estimate a reduction in Net income of approximately $670 million to $820 million for the full year 2021. The ultimate impact to Exelon’s and Generation’s consolidated financial statements may be affected by a number of factors, including final settlement data, the impacts of customer and counterparty credit losses, any state or federal solutions to address the financial challenges caused by the event, and related litigation and contract disputes. See Note 3 — Regulatory Matters and Note 14 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for additional information.

Exelon expects to offset between $410 million and $490 million of this impact for the full year 2021 primarily at Generation through a combination of enhanced revenue opportunities, deferral of selected non-essential maintenance, and primarily one-time cost savings.

Agreement for the Sale of a Generation Biomass Facility (Exelon and Generation)

On April 28, 2021, Generation and ReGenerate entered into a purchase agreement, under which ReGenerate agreed to purchase Generation's interest in the Albany Green Energy biomass facility. Completion of the transaction is expected in the second half of 2021.

As a result, in the second quarter of 2021, Exelon and Generation will reclassify these assets and liabilities as held for sale and expect to record an impairment loss in a range of $135 million to $150 million on a pre-tax basis, which will be excluded from Exelon’s and Generation’s Adjusted (non-GAAP) Operating Earnings. See Note 2 — Mergers, Acquisitions, and Dispositions of the Combined Notes to Consolidated Financial Statements for additional information.

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Utility Rates and Base Rate 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 2021. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information on these and other regulatory proceedings.

Completed Distribution Base Rate Case Proceedings

Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement (Decrease) Increase		Approved Revenue Requirement (Decrease) Increase		Approved ROE		Approval Date	Rate Effective Date
ComEd - Illinois	April 16, 2020	Electric	$	(11)	$	(14)	8.38	%	December 9, 2020	January 1, 2021
BGE - Maryland	May 15, 2020 (amended September 11, 2020)	Electric	137		81		9.50	%	December 16, 2020	January 1, 2021
		Natural Gas	91		21		9.65	%

Pending Distribution Base Rate Case Proceedings

Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement Increase		Requested ROE		Expected Approval Timing
ComEd - Illinois	April 16, 2021	Electric	$	51	7.36	%	Fourth quarter of 2021
PECO - Pennsylvania	March 30, 2021	Electric	246		10.95	%	Fourth quarter of 2021
PECO - Pennsylvania	September 30, 2020	Natural Gas	69		10.95	%	Second quarter of 2021
Pepco - District of Columbia	May 30, 2019 (amended June 1, 2020)	Electric	136		9.7	%	Second quarter of 2021
Pepco - Maryland	October 26, 2020 (amended March 31, 2021)	Electric	104		10.2	%	Second quarter of 2021
DPL - Delaware	March 6, 2020 (amended February 2, 2021)	Electric	23		10.3	%	Third quarter of 2021
ACE - New Jersey	December 9, 2020 (amended February 26, 2021)	Electric	67		10.3	%	Fourth quarter of 2021

Transmission Formula Rates

The following total increases were included in ComEd's 2021 electric transmission formula rate update. See Note 3 — Regulatory Matters of the Combined Notes to Consolidated Financial Statements for additional information.

Registrant	Initial Revenue Requirement Increase		Annual Reconciliation Increase		Total Revenue Requirement Increase		Allowed Return on Rate Base		Allowed ROE
ComEd	$	33	$	12	$	45	8.20	%	11.50	%

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Other Key Business Drivers and Management Strategies

The following discussion of other key business driver 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 and ITEM 7. Management's Discussion and Analysis of Financial Condition and Results of Operations — Other Key Business Drivers and Management Strategies in the Registrants' combined 2020 Form 10-K and Note 14 — Commitments and Contingencies to the Consolidated Financial Statements in this report for additional information on various environmental matters.

Power Markets

Complaint at FERC Seeking to Alter Capacity Market Default Offer Caps

On February 21, 2019, PJM's Independent Market Monitor (IMM) filed a complaint alleging that the number of performance assessment intervals used to calculate the default offer cap for bids to supply capacity in PJM is too high, resulting in an overstated default offer cap that obviates the need for most sellers to seek unit-specific approval of their offers. The IMM claims that this allows for the exercise of market power. The IMM asks FERC to require PJM to reduce the number of performance assessment intervals used to calculate the opportunity costs of a capacity supplier assuming a capacity obligation. This would, in turn, lower the default offer cap and allow the IMM to review more offers on a unit-specific basis. Several consumer advocates filed a complaint seeking similar relief several months after the IMM’s complaint. On March 18, 2021, FERC granted the complaints, finding the current estimate of performance assessment intervals to be excessive compared to the reasonably expected number of performance assessment intervals which results in an unjust and unreasonable default offer cap. FERC did not establish the number of performance assessment intervals that should be used to calculate the default offer cap and instead request briefs on the matter, including alternative approaches to mitigation in the capacity market. FERC clarified that the capacity auction for delivery year 2022/2023 (scheduled for May 2021) should go forward as scheduled under the current rules. It is too early to predict the final outcome of this proceeding or its potential financial impact, if any, on Exelon or Generation.

Hedging Strategy

Exelon’s policy to hedge commodity risk on a ratable basis over three-year periods is intended to reduce the financial impact of market price volatility. Generation is exposed to commodity price risk associated with the unhedged portion of its electricity portfolio. Generation enters into non-derivative and derivative contracts, including financially-settled swaps, futures contracts and swap options, and physical options and physical forward contracts, all with credit-approved counterparties, to hedge this anticipated exposure. As of March 31, 2021, the percentage of expected generation hedged for the Mid-Atlantic, Midwest, New York, and ERCOT reportable segments is 94%-97% for 2021. Generation has been and will continue to be proactive in using hedging strategies to mitigate commodity price risk.

Generation procures natural gas through long-term and short-term contracts and spot-market purchases. Nuclear fuel assemblies are obtained predominantly through long-term uranium concentrate supply contracts, contracted conversion services, contracted enrichment services, or a combination thereof, and contracted fuel fabrication services. The supply markets for uranium concentrates and certain nuclear fuel services are subject to price fluctuations and availability restrictions. Approximately 60% of Generation’s uranium concentrate requirements from 2021 through 2025 are supplied by three suppliers. In the event of non-performance by these or other suppliers, Generation believes that replacement uranium concentrate can be obtained, although at prices that may be unfavorable when compared to the prices under the current supply agreements. Non-performance by these counterparties could have a material adverse impact on Exelon’s and Generation’s consolidated financial statements.

See Note 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements and ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK for additional information.

The Utility Registrants mitigate commodity price risk through regulatory mechanisms that allow them to recover procurement costs from retail customers.

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Other Legislative and Regulatory Developments

FERC Supplemental Notice of Proposed Rulemaking

On April 15, 2021, the FERC issued a Supplemental Notice of Proposed Rulemaking (NOPR) proposing to modify the current regulation permitting a continuous 50-basis-point ROE incentive adder for a transmission utility that joins and remains a member of a RTO. Under the NOPR, the ROE incentive adder would only be available for a period of up to three years after a transmission utility newly joins a RTO and all existing ROE incentive adders would end for transmission utilities that have been members for three or more years. The Utility Registrants’ existing transmission rates include the ROE incentive adder. Exelon plans to provide comments to FERC on this matter which are due by May 26, 2021. Exelon cannot predict the outcome, but a final rule as proposed could have an adverse impact to Exelon’s and the Utility Registrants’ financial statements. See Note 3 — Regulatory Matters of the 2020 Form 10-K for additional information regarding the Utility Registrants’ transmission formula rates and regulatory proceedings at the FERC.

Employees

In April 2021, PECO ratified two CBAs with IBEW Local 614 which covers 1,140 operations employees and 185 customer service employees, respectively. Both CBAs expire in 2026.

Critical Accounting Policies and Estimates

Management of each of the Registrants makes a number of significant estimates, assumptions, and judgments in the preparation of its financial statements. At March 31, 2021, the Registrants’ critical accounting policies and estimates had not changed significantly from December 31, 2020. See ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS — Critical Accounting Policies and Estimates in the Registrants' 2020 Form 10-K for further information.

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Generation

Results of Operations by Registrant

Results of Operations — Generation

Generation’s Results of Operations includes discussion of RNF, which is a financial measure not 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 CODMs for Exelon and Generation evaluate the performance of Generation's electric business activities and allocate resources based on RNF. Generation believes that RNF is a useful measure because it provides information that can be used to evaluate its operational performance.

	Three Months Ended March 31,				Favorable (Unfavorable) Variance
	2021		2020
Operating revenues	$	5,559	$	4,733	$	826
Purchased power and fuel expense	4,610		2,704		(1,906)
Revenues net of purchased power and fuel expense	949		2,029		(1,080)
Other operating expenses
Operating and maintenance	1,001		1,263		262
Depreciation and amortization	940		304		(636)
Taxes other than income taxes	121		129		8
Total other operating expenses	2,062		1,696		(366)
Gain on sales of assets and businesses	71		—		71
Operating (loss) income	(1,042)		333		(1,375)
Other income and (deductions)
Interest expense, net	(72)		(109)		37
Other, net	167		(771)		938
Total other income and (deductions)	95		(880)		975
Loss before income taxes	(947)		(547)		(400)
Income taxes	(179)		(389)		(210)
Equity in losses of unconsolidated affiliates	(1)		(3)		2
Net loss	(769)		(161)		(608)
Net income (loss) attributable to noncontrolling interests	24		(206)		230
Net (loss) income attributable to membership interest	$	(793)	$	45	$	(838)

Three Months Ended March 31, 2021 Compared to Three Months Ended March 31, 2020. Net income attributable to membership interest decreased by $838 million primarily due to:

•Impacts of the February 2021 extreme cold weather event;

•Accelerated depreciation and amortization associated with Generation's decisions in the third quarter of
    2020 to early retire Byron and Dresden nuclear facilities in 2021 and Mystic Units 8 and 9 in 2024; and

•The absence of a prior year one-time tax settlement.

The decreases were partially offset by:

•Lower unrealized losses and higher realized gains on NDT funds.

Revenues Net of Purchased Power and Fuel Expense. The basis for Generation's reportable segments is the integrated management of its electricity business that is located in different geographic regions, and largely representative of the footprints of ISO/RTO and/or NERC regions, which utilize multiple supply sources to provide electricity through various distribution channels (wholesale and retail). Generation's hedging strategies and risk metrics are also aligned with these same geographic regions. Generation's five reportable segments are Mid-

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Generation

Atlantic, Midwest, New York, ERCOT, and Other Power Regions. See Note 5 - Segment Information of the Combined Notes to Consolidated Financial Statements for additional information on these reportable segments.

The following business activities are not allocated to a region and are reported under Other: natural gas, as well as other miscellaneous business activities that are not significant to overall operating revenues or results of operations. Further, the following activities are not allocated to a region and are reported in Other: accelerated nuclear fuel amortization associated with nuclear decommissioning and other miscellaneous revenues.

Generation evaluates the operating performance of electric business activities using the measure of RNF. Operating revenues include all sales to third parties and affiliated sales to the Utility Registrants. Purchased power costs include all costs associated with the procurement and supply of electricity including capacity, energy and ancillary services. Fuel expense includes the fuel costs for owned generation and fuel costs associated with tolling agreements.

For the three months ended March 31, 2021 compared to 2020, RNF by region were as follows. See Note 5 - Segment Information of the Combined Notes to the Consolidated Financial Statements for additional information on Purchase power and fuel expense for Generation’s reportable segments.

	Three Months Ended March 31,				Variance		% Change
	2021		2020
Mid-Atlantic(a)	$	567	$	567	$	—	—	%
Midwest(b)	702		727		(25)		(3.4)	%
New York	242		193		49		25.4	%
ERCOT	(1,184)		80		(1,264)		(1,580.0)	%
Other Power Regions	217		158		59		37.3	%
Total electric revenues net of purchased power and fuel expense	544		1,725		(1,181)		(68.5)	%
Mark-to-market gains	175		131		44		33.6	%
Other	230		173		57		32.9	%
Total revenue net of purchased power and fuel expense	$	949	$	2,029	$	(1,080)	(53.2)	%

__________

(a)Includes results of transactions with PECO, BGE, Pepco, DPL, and ACE.

(b)Includes results of transactions with ComEd.

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Generation

Generation’s supply sources by region are summarized below:

	Three Months Ended March 31,		Variance	% Change
Supply Source (GWhs)	2021	2020
Nuclear Generation(a)
Mid-Atlantic	13,254	12,784	470	3.7	%
Midwest	23,155	23,598	(443)	(1.9)	%
New York	7,057	6,173	884	14.3	%
Total Nuclear Generation	43,466	42,555	911	2.1	%
Fossil and Renewables
Mid-Atlantic	662	853	(191)	(22.4)	%
Midwest	323	388	(65)	(16.8)	%
New York	1	1	—	—	%
ERCOT	2,783	3,012	(229)	(7.6)	%
Other Power Regions	2,964	3,508	(544)	(15.5)	%
Total Fossil and Renewables	6,733	7,762	(1,029)	(13.3)	%
Purchased Power
Mid-Atlantic	4,483	5,943	(1,460)	(24.6)	%
Midwest	179	288	(109)	(37.8)	%
ERCOT	772	991	(219)	(22.1)	%
Other Power Regions	12,834	12,167	667	5.5	%
Total Purchased Power	18,268	19,389	(1,121)	(5.8)	%
Total Supply/Sales by Region
Mid-Atlantic(b)	18,399	19,580	(1,181)	(6.0)	%
Midwest(b)	23,657	24,274	(617)	(2.5)	%
New York	7,058	6,174	884	14.3	%
ERCOT	3,555	4,003	(448)	(11.2)	%
Other Power Regions	15,798	15,675	123	0.8	%
Total Supply/Sales by Region	68,467	69,706	(1,239)	(1.8)	%

__________

(a)Includes the proportionate share of output where Generation has an undivided ownership interest in jointly-owned generating plants and includes the total output of plants that are fully consolidated (e.g. CENG).

(b)Includes affiliate sales to PECO, BGE, Pepco, DPL, and ACE in the Mid-Atlantic region and affiliate sales to ComEd in the Midwest region.

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Generation

For the three months ended March 31, 2021 compared to 2020, changes in RNF by region were as follows:

	(Decrease)/ Increase		2021 vs. 2020
			Description
Mid-Atlantic	$	—	• increased capacity revenue, offset by • decreased load served
Midwest	(25)		• decreased load served • decreased total ISO sales due to decreased generation
New York	49		• decreased nuclear outage days • increased ZEC revenues due to decreased nuclear outage days
ERCOT	(1,264)		• higher energy procurement costs due to the February 2021 extreme cold weather event, as well as the impact of ERCOT market participant defaults
Other Power Regions	59		• increase in newly contracted load • higher portfolio optimization • higher realized energy prices, partially offset by • decreased capacity revenue
Mark-to-market(a)	44		• gains on economic hedging activities of $131 million in 2020 compared to gains of $175 million in 2021
Other	57		• higher natural gas portfolio optimization partially offset by penalties associated with operational flow orders and curtailments as a result of the February 2021 extreme cold weather event, partially offset by • increase in accelerated nuclear fuel amortization associated with announced early plant retirements • decreased revenue related to the energy efficiency business
Total	$	(1,080)

__________

(a)See Note 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information on mark-to-market gains.

Nuclear Fleet Capacity Factor. The following table presents nuclear fleet operating data for the Generation-operated plants, which reflects ownership percentage of stations operated by Exelon, excluding Salem, which is operated by PSEG. The nuclear fleet capacity factor presented in the table is defined as the ratio of the actual output of a plant over a period of time to its output if the plant had operated at full average annual mean capacity for that time period. Generation considers capacity factor to be a useful measure to analyze the nuclear fleet performance between periods. Generation has included the analysis below as a complement to the financial information provided in accordance with GAAP. However, these measures are not a presentation defined under

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Generation

GAAP and may not be comparable to other companies’ presentations or be more useful than the GAAP information provided elsewhere in this report.

	Three Months Ended March 31,
	2021		2020
Nuclear fleet capacity factor	95.3	%	93.9	%
Refueling outage days	84		94
Non-refueling outage days	3		11

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

	Three Months Ended March 31, 2021
	Increase (Decrease)
Credit loss expense	$	47
Labor, other benefits, contracting, and materials(a)	(27)
Nuclear refueling outage costs, including the co-owned Salem plants	(51)
Plant retirements and divestitures	(221)
Other	(10)
Total decrease	$	(262)

__________ 

(a)Primarily reflects decreased contracting costs.

Depreciation and amortization expense for the three months ended March 31, 2021 compared to the same period in 2020 increased primarily due to the accelerated depreciation and amortization associated with Generation's decision to early retire the Byron and Dresden nuclear facilities.

Gain on sales of assets and businesses for the three months ended March 31, 2021 compared to the same period in 2020 increased primarily due to a gain on sale of Generation's solar business.

Interest Expense for the three months ended March 31, 2021 compared to the same period in 2020 decreased primarily due to decreases in interest rates.

Other, net for the three months ended March 31, 2021 compared to the same period in 2020 increased due to activity described in the table below:

	Three Months Ended March 31,
	2021		2020
Net unrealized losses on NDT funds(a)	$	(66)	$	(706)
Net realized gains on sale of NDT funds(a)	185		55
Interest and dividend income on NDT funds(a)	18		27
Contractual elimination of income tax expense(b)	42		(176)
Net unrealized losses from equity investments(c)	(23)		—
Other	11		29
Total other, net	$	167	$	(771)

__________ 

(a)Unrealized losses, realized gains, and interest and dividend income on the NDT funds are associated with the Non-Regulatory Agreement Units.

(b)Contractual elimination of income tax expense is associated with the income taxes on the NDT funds of the Regulatory Agreement units.

(c)Net unrealized losses on equity investments that became publicly traded entities in the fourth quarter of 2020 and the first quarter of 2021.

132

Generation

Effective income tax rates were 18.9% and 71.1% for the three months ended March 31, 2021 and 2020, respectively. See Note 9 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information

Net income attributable to noncontrolling interests for the three months ended March 31, 2021 compared to the same period in 2020 increased primarily due to higher net gains on NDT fund investments for CENG.

133

ComEd

Results of Operations — ComEd

	Three Months Ended March 31,				Favorable (Unfavorable) Variance
	2021		2020
Operating revenues	$	1,535	$	1,439	$	96
Operating expenses
Purchased power expense	527		486		(41)
Operating and maintenance	316		317		1
Depreciation and amortization	292		273		(19)
Taxes other than income taxes	75		75		—
Total operating expenses	1,210		1,151		(59)
Operating income	325		288		37
Other income and (deductions)
Interest expense, net	(96)		(94)		(2)
Other, net	7		10		(3)
Total other income and (deductions)	(89)		(84)		(5)
Income before income taxes	236		204		32
Income taxes	39		36		(3)
Net income	$	197	$	168	$	29

Three Months Ended March 31, 2021 Compared to Three Months Ended March 31, 2020. Net income increased $29 million as compared to the same period in 2020, primarily due to increased electric distribution formula rate earnings (reflecting the impacts of higher rate base and higher allowed electric distribution ROE due to an increase in treasury rates).

The changes in Operating revenues consisted of the following:

	Three Months Ended March 31, 2021
	Increase
Distribution	$	21
Transmission	2
Energy efficiency	12
Other	12
	47
Regulatory required programs	49
Total increase	$	96

Revenue Decoupling. The demand for electricity is affected by weather conditions and customer usage. Operating revenues are not impacted by abnormal weather, usage per customer or number of customers as a result of the revenue decoupling mechanisms as allowed by FEJA.

Distribution Revenue. EIMA and FEJA provide for a performance-based formula rate, which requires an annual reconciliation of the revenue requirement in effect to the actual costs that the ICC determines are prudently and reasonably incurred in a given year. Electric distribution revenue varies from year to year based upon fluctuations in the underlying costs, (e.g., severe weather and storm restoration), investments being recovered, and allowed ROE. Electric distribution revenue increased for the three months ended March 31, 2021 as compared to the same period in 2020, due to the impact of higher rate base and higher allowed ROE due to an increase in treasury rates.

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.

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ComEd

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 during the three months ended March 31, 2021 as compared to the same period in 2020, primarily due to increased regulatory asset amortization, which is fully recoverable.

Other Revenue primarily includes assistance provided to other utilities through mutual assistance programs. The increase in Other revenue for the three months ended March 31, 2021 as compared to the same period in 2020, primarily reflects mutual assistance revenues associated with storm restoration efforts.

Regulatory Required Programs represents revenues collected under approved riders to recover costs incurred for regulatory programs such as recoveries under the credit loss expense tariff, environmental costs associated with MGP sites, and costs related to electricity, ZEC and REC procurement. 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 acts as the billing agent 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, 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 ComEd's revenue disaggregation.

The increase of $41 million for the three months ended March 31, 2021 compared to the same period in 2020, respectively, in Purchased power expense is offset in Operating revenues as part of regulatory required programs.

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

	Three Months Ended March 31, 2021
	(Decrease) Increase
Storm-related costs	$	(9)
Labor, other benefits, contracting and materials	8
Pension and non-pension postretirement benefits expense	1
Other	(6)
	(6)
Regulatory required programs(a)	5
Total decrease	$	(1)

__________

(a)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.

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ComEd

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

	Three Months Ended March 31, 2021
	Increase
Depreciation and amortization(a)	$	11
Regulatory asset amortization(b)	8
Total increase	$	19

__________

(a)Reflects ongoing capital expenditures.

(b)Includes amortization of ComEd's energy efficiency formula rate regulatory asset and amortization related to the August 2020 storm regulatory asset.

Effective income tax rates were 16.5% and 17.6% for the three months ended March 31, 2021 and 2020, respectively. See Note 9 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the effective income tax rates.

136

PECO

Results of Operations — PECO

	Three Months Ended March 31,				Favorable (Unfavorable) Variance
	2021		2020
Operating revenues	$	889	$	813	$	76
Operating expenses
Purchased power and fuel expense	316		283		(33)
Operating and maintenance	234		217		(17)
Depreciation and amortization	86		86		—
Taxes other than income taxes	43		39		(4)
Total operating expenses	679		625		(54)
Operating income	210		188		22
Other income and (deductions)
Interest expense, net	(38)		(36)		(2)
Other, net	5		3		2
Total other income and (deductions)	(33)		(33)		—
Income before income taxes	177		155		22
Income taxes	10		15		5
Net income	$	167	$	140	$	27

Three Months Ended March 31, 2021 Compared to Three Months Ended March 31, 2020. Net income increased by $27 million primarily due to favorable weather conditions and volume.

The changes in Operating revenues consisted of the following:

	Three Months Ended March 31, 2021
	Increase (Decrease)
	Electric		Gas		Total
Weather	$	21	$	16	$	37
Volume	12		2		14
Pricing	(6)		(1)		(7)
Transmission	1		—		1
Other	(2)		—		(2)
	26		17		43
Regulatory required programs	31		2		33
Total increase	$	57	$	19	$	76

Weather. The demand for electricity and natural gas is affected by weather conditions. With respect to the electric business, very warm weather in summer months and, with respect to the electric and natural gas businesses, very cold weather in winter months are referred to as “favorable weather conditions” because these weather conditions result in increased deliveries of electricity and natural gas. Conversely, mild weather reduces demand. During the three months ended March 31, 2021 compared to the same period in 2020, Operating revenues related to weather increased by the impact of favorable 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

137

PECO

PECO’s service territory for the three months ended March 31, 2021 compared to the same period in 2020 and normal weather consisted of the following:

Heating and Cooling Degree-Days			Normal	% Change
	2021	2020		From 2020		2021 vs. Normal
Three Months Ended March 31,
Heating Degree-Days	2,302	1,989	2,418	15.7	%	(4.8)	%
Cooling Degree-Days	5	—	1	n/a		400.0	%

Volume. Electric volume, exclusive of the effects of weather, for the three months ended March 31, 2021, compared to the same period in 2020, increased on a net basis due to an increase in usage for residential customers further increased by customer growth. Natural gas volume for the three months ended March 31, compared to the same period in 2020, remained relatively consistent.

Electric Retail Deliveries to Customers (in GWhs)	Three Months Ended March 31,		% Change		Weather - Normal % Change(b)
	2021	2020
Residential	3,767	3,254	15.8	%	6.2	%
Small commercial & industrial	1,881	1,905	(1.3)	%	(5.1)	%
Large commercial & industrial	3,272	3,421	(4.4)	%	(5.0)	%
Public authorities & electric railroads	149	151	(1.3)	%	(1.4)	%
Total electric retail deliveries(a)	9,069	8,731	3.9	%	(0.6)	%

	As of March 31,
Number of Electric Customers	2021	2020
Residential	1,512,255	1,499,019
Small commercial & industrial	154,637	154,056
Large commercial & industrial	3,109	3,093
Public authorities & electric railroads	10,237	10,096
Total	1,680,238	1,666,264

__________

(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 March 31,		% Change		Weather - Normal % Change(b)
	2021	2020
Residential	20,674	17,282	19.6	%	2.8	%
Small commercial & industrial	10,170	8,809	15.5	%	(0.2)	%
Large commercial & industrial	7	9	(22.2)	%	(0.6)	%
Transportation	7,650	7,135	7.2	%	0.4	%
Total natural gas retail deliveries(a)	38,501	33,235	15.8	%	1.5	%

	As of March 31,
Number of Natural Gas Customers	2021	2020
Residential	493,857	489,063
Small commercial & industrial	44,604	44,509
Large commercial & industrial	5	5
Transportation	685	727
Total	539,151	534,304

__________

(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.

138

PECO

Pricing for the three months ended March 31, 2021 compared to the same period in 2020 decreased primarily due to lower overall effective electric rates due to increased usage across all major customer classes.

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.

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 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 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.

Other revenue primarily includes revenue related to late payment charges. Other revenues for the three months ended March 31, 2021 compared to the same period in 2020, decreased as PECO ceased new late fees for all customers and restored service to customers upon request who were disconnected in the last twelve months beginning March of 2020.

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

The increase of $33 million for the three months ended March 31, 2021 compared to the same period in 2020, 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 March 31, 2021
	Increase (Decrease)
Labor, other benefits, contracting and materials	10
Credit loss expense	7
Storm-related costs	6
BSC costs	3
Regulatory Required Programs	(2)
Other	(7)
Total increase	$	17

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

	Three Months Ended March 31, 2021
	Increase (Decrease)
Depreciation and amortization(a)	$	3
Regulatory asset amortization	(3)
Total increase	$	—

__________

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

Interest expense, net increased $2 million for the three months ended March 31, 2021 compared to the same period in 2020, respectively, primarily due to the issuance of debt in June 2020 and March 2021.

139

PECO

Effective income tax rates were 5.6% and 9.7% for the three months ended March 31, 2021 and 2020, respectively. See Note 9 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the effective income tax rates.

140

BGE

Results of Operations — BGE

	Three Months Ended March 31,				Favorable (Unfavorable) Variance
	2021		2020
Operating revenues	$	974	$	937	$	37
Operating expenses
Purchased power and fuel expense	331		288		(43)
Operating and maintenance	197		188		(9)
Depreciation and amortization	152		143		(9)
Taxes other than income taxes	72		69		(3)
Total operating expenses	752		688		(64)
Operating income	222		249		(27)
Other income and (deductions)
Interest expense, net	(34)		(32)		(2)
Other, net	8		5		3
Total other income and (deductions)	(26)		(27)		1
Income before income taxes	196		222		(26)
Income taxes	(13)		41		54
Net income	$	209	$	181	$	28

Three Months Ended March 31, 2021 Compared to Three Months Ended March 31, 2020. Net income increased by $28 million primarily due to favorable impacts of the multi-year plan. 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 plan.

The changes in Operating revenues consisted of the following:

	Three Months Ended March 31, 2021
	(Decrease) Increase
	Electric		Gas		Total
Distribution	$	—	$	(1)	$	(1)
Transmission	3		—		3
Other	(7)		(1)		(8)
	(4)		(2)		(6)
Regulatory required programs	24		19		43
Total increase	$	20	$	17	$	37

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 bill stabilization adjustment (BSA) that provides for a fixed distribution charge per customer by customer class. While Operating revenues are not impacted by abnormal weather or usage per customer, they are impacted by changes in the number of customers.

	As of March 31,
Number of Electric Customers	2021	2020
Residential	1,192,470	1,181,329
Small commercial & industrial	114,819	114,697
Large commercial & industrial	12,505	12,376
Public authorities & electric railroads	266	265
Total	1,320,060	1,308,667

141

BGE

	As of March 31,
Number of Natural Gas Customers	2021	2020
Residential	648,824	641,608
Small commercial & industrial	38,318	38,381
Large commercial & industrial	6,120	6,078
Total	693,262	686,067

Distribution Revenue remained relatively consistent for the three months ended March 31, 2021, compared to the same period in 2020.

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.

Other Revenue includes revenue related to late payment charges, mutual assistance, off-system sales, and service application fees.

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 $43 million for the three months ended March 31, 2021 compared to the same period in 2020, in Purchased power and fuel expense is fully offset in Operating revenues as part of regulatory required programs.

142

BGE

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

	Three Months Ended March 31, 2021
	Increase (Decrease)
Storm-related costs	$	6
BSC costs	2
Credit loss expense	(2)
Other	3
Total increase	$	9

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

	Three Months Ended March 31, 2021
	Increase
Depreciation and amortization(a)	$	9
Total increase	$	9

_________

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

Effective income tax rates were (6.6)% and 18.5% for the three months ended March 31, 2021 and 2020, respectively. The change is primarily due to the multi-year plan which resulted in the acceleration of certain income tax benefits. 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 plan and Note 9 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the effective income tax rates.

143

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 months ended March 31, 2021 compared to the same period in 2020. See the Results of Operations for Pepco, DPL, and ACE for additional information.

	Three Months Ended March 31,				Favorable Variance
	2021		2020
PHI	$	128	$	108	$	20
Pepco	59		52		7
DPL	56		45		11
ACE	14		13		1
Other(a)	(1)		(2)		1

_________

(a)Primarily includes eliminating and consolidating adjustments, PHI's corporate operations, shared service entities, and other financing and investing activities.

Three Months Ended March 31, 2021 Compared to Three Months Ended March 31, 2020. Net Income increased by $20 million primarily due to favorable weather conditions in DPL's Delaware and ACE's service territories and higher electric distribution rates at DPL.

144

Pepco

Results of Operations — Pepco

	Three Months Ended March 31,				Favorable (Unfavorable) Variance
	2021		2020
Operating revenues	$	553	$	544	$	9
Operating expenses
Purchased power expense	166		164		(2)
Operating and maintenance	108		111		3
Depreciation and amortization	102		95		(7)
Taxes other than income taxes	90		92		2
Total operating expenses	466		462		(4)
Operating income	87		82		5
Other income and (deductions)
Interest expense, net	(34)		(34)		—
Other, net	12		9		3
Total other income and (deductions)	(22)		(25)		3
Income before income taxes	65		57		8
Income taxes	6		5		(1)
Net income	$	59	$	52	$	7

Three Months Ended March 31, 2021 Compared to Three Months Ended March 31, 2020. Net income remained relatively consistent.

The changes in Operating revenues consisted of the following:

	Three Months Ended March 31, 2021
	Increase (Decrease)
Distribution	$	3
Transmission	(3)
Other	4
	4
Regulatory required programs	5
Total increase	$	9

Revenue Decoupling. The demand for electricity is affected by weather and customer usage. However, Operating revenues from electric distribution in both Maryland and the District of Columbia are not impacted by abnormal weather or usage per customer as a result of a bill stabilization adjustment (BSA) that provides for a fixed distribution charge per customer by customer class. While Operating revenues are not impacted by abnormal weather or usage per customer, they are impacted by changes in the number of customers.

	As of March 31,
Number of Electric Customers	2021	2020
Residential	835,415	820,283
Small commercial & industrial	53,738	54,304
Large commercial & industrial	22,492	22,248
Public authorities & electric railroads	174	169
Total	911,819	897,004

Distribution Revenue increased for the three months ended March 31, 2021 compared to the same period in 2020, due to customer growth.

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.

145

Pepco

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 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 $2 million for the three months ended March 31, 2021 compared to the same period in 2020, in Purchased power expense is fully offset in Operating revenues as part of regulatory required programs.

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

	Three Months Ended March 31, 2021
	(Decrease) Increase
Labor, other benefits, contracting and materials	$	(6)
Pension and non-pension postretirement benefits expense	(1)
BSC and PHISCO costs	1
Credit loss expense	2
Other	1
Total decrease	$	(3)

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

	Three Months Ended March 31, 2021
	Increase (Decrease)
Depreciation and amortization(a)	$	4
Regulatory asset amortization	(1)
Regulatory required programs	4
Total increase	$	7

_________

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

Effective income tax rates were 9.2% and 8.8% for the three months ended March 31, 2021 and 2020, respectively. See Note 9 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the change in effective income tax rates.

146

DPL

Results of Operations — DPL

	Three Months Ended March 31,				Favorable (Unfavorable) Variance
	2021		2020
Operating revenues	$	382	$	350	$	32
Operating expenses
Purchased power and fuel expense	156		141		(15)
Operating and maintenance	83		79		(4)
Depreciation and amortization	53		48		(5)
Taxes other than income taxes	17		16		(1)
Total operating expenses	309		284		(25)
Operating income	73		66		7
Other income and (deductions)
Interest expense, net	(15)		(16)		1
Other, net	3		2		1
Total other income and (deductions)	(12)		(14)		2
Income before income taxes	61		52		9
Income taxes	5		7		2
Net income	$	56	$	45	$	11

Three Months Ended March 31, 2021 Compared to Three Months Ended March 31, 2020. Net income increased by $11 million primarily due to favorable weather conditions in DPL's Delaware electric and natural gas service territories and higher electric distribution rates.

The changes in Operating revenues consisted of the following:

	Three Months Ended March 31, 2021
	Increase (Decrease)
	Electric		Gas		Total
Weather	$	4	$	5	$	9
Volume	—		1		1
Distribution	5		—		5
Other	1		(1)		—
	10		5		15
Regulatory required programs	15		2		17
Total increase	$	25	$	7	$	32

Revenue Decoupling. The demand for electricity is affected by weather and customer usage. However, Operating revenues from electric distribution in Maryland are not impacted by abnormal weather or usage per customer as a result of a bill stabilization adjustment (BSA) that provides for a fixed distribution charge per customer by customer class. While Operating revenues from electric distribution customers in Maryland are not impacted by abnormal weather or usage per customer, they are impacted by changes in the number of customers.

Weather. The demand for electricity and natural gas in Delaware is affected by weather conditions. With respect to the electric business, very warm weather in summer months and, with respect to the electric and natural gas businesses, very cold weather in winter months are referred to as "favorable weather conditions” because these weather conditions result in increased deliveries of electricity and natural gas. Conversely, mild weather reduces demand. During the three months ended March 31, 2021 compared to the same period in 2020, Operating revenues related to weather increased due to the impact of favorable weather conditions in DPL's Delaware electric and natural gas service territories.

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DPL

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 months ended March 31, 2021 compared to same period in 2020 and normal weather consisted of the following:

Delaware Electric Service Territory				% Change
Three Months Ended March 31,	2021	2020	Normal	2021 vs. 2020		2021 vs. Normal
Heating Degree-Days	2,358	2,003	2,493	17.7	%	(5.4)	%
Cooling Degree-Days	3	—	—	n/a		n/a

Delaware Natural Gas Service Territory				% Change
Three Months Ended March 31,	2021	2020	Normal	2021 vs. 2020		2021 vs. Normal
Heating Degree-Days	2,358	2,003	2,497	17.7	%	(5.6)	%

Volume, exclusive of the effects of weather, remained relatively consistent for the three months ended March 31, 2021 compared to the same period in 2020.

Electric Retail Deliveries to Delaware Customers (in GWhs)	Three Months Ended March 31,		% Change		Weather - Normal % Change(b)
	2021	2020
Residential	854	743	14.9	%	4.5	%
Small commercial & industrial	342	296	15.5	%	10.5	%
Large commercial & industrial	689	823	(16.3)	%	(17.2)	%
Public authorities & electric railroads	9	8	12.5	%	7.7	%
Total electric retail deliveries(a)	1,894	1,870	1.3	%	(3.6)	%

	As of March 31,
Number of Total Electric Customers (Maryland and Delaware)	2021	2020
Residential	473,917	469,082
Small commercial & industrial	62,647	61,769
Large commercial & industrial	1,208	1,414
Public authorities & electric railroads	608	612
Total	538,380	532,877

_________

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

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

Natural Gas Retail Deliveries to Delaware Customers (in mmcf)	Three Months Ended March 31,		% Change		Weather - Normal % Change(b)
	2021	2020
Residential	4,394	3,647	20.5	%	2.6	%
Small commercial & industrial	1,868	1,671	11.8	%	(3.9)	%
Large commercial & industrial	457	452	1.1	%	1.1	%
Transportation	2,224	2,108	5.5	%	(0.9)	%
Total natural gas deliveries(a)	8,943	7,878	13.5	%	0.2	%

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DPL

	As of March 31,
Number of Delaware Natural Gas Customers	2021	2020
Residential	127,522	126,209
Small commercial & industrial	10,043	10,004
Large commercial & industrial	19	17
Transportation	160	159
Total	137,744	136,389

__________

(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 months ended March 31, 2021 compared to the same period in 2020 primarily due to higher electric distribution rates in Maryland that became effective in July 2020 and higher electric and natural gas distribution rates in Delaware that became effective in the second half of 2020.

Transmission Revenues. 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.

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. Customers have the choice to purchase electricity from competitive electric generation 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 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 DPL, DPL is permitted to recover the electricity, natural gas, and REC procurement costs from customers and therefore records the amounts related to the electricity, natural gas, and RECs in Operating revenues and Purchased power and fuel expense. DPL recovers electricity and REC procurement costs from customers with a slight mark-up and natural gas costs without mark-up.

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

The increase of $15 million for the three months ended March 31, 2021, compared to the same period in 2020, 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 March 31, 2021
	Increase (Decrease)
Labor, other benefits, contracting and materials	$	2
BSC and PHISCO costs	2
Credit loss expense	1
Pension and non-pension postretirement benefits expense	(1)
Total increase	$	4

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DPL

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

	Three Months Ended March 31, 2021
	Increase
Depreciation and amortization(a)	$	3
Regulatory required programs	2
Total increase	$	5

_________

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

Effective income tax rates were 8.2% and 13.5% for the three months ended March 31, 2021 and 2020, respectively. See Note 9 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the change in effective income tax rates.

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ACE

Results of Operations — ACE

	Three Months Ended March 31,				Favorable (Unfavorable) Variance
	2021		2020
Operating revenues	$	310	$	276	$	34
Operating expenses
Purchased power expense	157		128		(29)
Operating and maintenance	76		78		2
Depreciation and amortization	47		43		(4)
Taxes other than income taxes	2		2		—
Total operating expenses	282		251		(31)
Gain on sale of assets	—		2		(2)
Operating income	28		27		1
Other income and (deductions)
Interest expense, net	(15)		(15)		—
Other, net	1		2		(1)
Total other income and (deductions)	(14)		(13)		(1)
Income before income taxes	14		14		—
Income taxes	—		1		1
Net income	$	14	$	13	$	1

Three Months Ended March 31, 2021 Compared to Three Months Ended March 31, 2020. Net income remained relatively consistent.

The changes in Operating revenues consisted of the following:

	Three Months Ended March 31, 2021
	Increase (Decrease)
Weather	$	4
Volume	2
Distribution	(1)
Other	1
	6
Regulatory required programs	28
Total increase	$	34

Weather. The demand for electricity is 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. There was an increase related to weather for the three months ended March 31, 2021 compared to same period in 2020 due to the impact of favorable weather conditions in ACE'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 20-year period in ACE’s service territory. The changes in heating and cooling degree days in ACE’s service territory for the three months ended March 31, 2021 compared to same period in 2020 and normal weather consisted of the following:

Heating and Cooling Degree-Days				% Change
Three Months Ended March 31,	2021	2020	Normal	2021 vs. 2020		2021 vs. Normal
Heating Degree-Days	2,348	1,948	2,469	20.5	%	(4.9)	%
Cooling Degree-Days	4	—	—	n/a		n/a

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ACE

Volume, exclusive of the effects of weather, increased for the three months ended March 31, 2021 compared to the same period in 2020, primarily due to residential customer growth and usage, partially offset by lower commercial and industrial usage.

Electric Retail Deliveries to Customers (in GWhs)	Three Months Ended March 31,		% Change		Weather - Normal % Change(b)
	2021	2020
Residential	928	810	14.6	%	6.6	%
Small commercial & industrial	305	294	3.7	%	(0.8)	%
Large commercial & industrial	716	735	(2.6)	%	(3.5)	%
Public authorities & electric railroads	13	13	—	%	0.9	%
Total electric retail deliveries(a)	1,962	1,852	5.9	%	1.5	%

	As of March 31,
Number of Electric Customers	2021	2020
Residential	498,396	495,444
Small commercial & industrial	61,771	61,470
Large commercial & industrial	3,267	3,355
Public authorities & electric railroads	704	684
Total	564,138	560,953

_________

(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 remained relatively consistent for the three months ended March 31, 2021 compared to the same period in 2020.

Transmission Revenues. 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.

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 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 increase of $29 million for the three months ended March 31, 2021 compared to the same period in 2020, 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 March 31, 2021
	Increase (Decrease)
Labor, other benefits, contracting and materials	$	1
BSC and PHISCO costs	1
	2
Regulatory required programs(a)	(4)
Total decrease	$	(2)

_________

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

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

	Three Months Ended March 31, 2021
	Increase (Decrease)
Depreciation and amortization(a)	$	4
Regulatory asset amortization	(1)
Regulatory required programs	1
Total increase	$	4

_________

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

Gain on sale of assets for the three months ended March 31, 2021 compared to the same period in 2020 decreased due to the sale of land in the first quarter of 2020.

Effective income tax rates were 0.0% and 7.1% for the three months ended March 31, 2021 and 2020, respectively. See Note 9 — Income Taxes of the Combined Notes to Consolidated Financial Statements for additional information regarding the components of the change in effective income tax rates.

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Liquidity and Capital Resources

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, the sale of certain receivables, 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, retire debt, pay dividends, fund pension and OPEB obligations, and invest in new and existing ventures. A broad spectrum of financing alternatives beyond the core financing options can be used to meet its needs and fund growth including monetizing assets in the portfolio via project financing, asset sales, and the use of other financing structures (e.g., joint ventures, minority partners, etc.). 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 $10.6 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” section below for additional information. The Registrants expect cash flows to be sufficient to meet operating expenses, financing costs, and capital expenditure requirements.

The Registrants primarily use their capital resources, including cash, to fund capital requirements, including construction expenditures, retire debt, pay dividends, fund pension and OPEB obligations, and invest in new and existing ventures. 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. See Note 12 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on the Registrants’ debt and credit agreements.

NRC Minimum Funding Requirements (Exelon and Generation)

NRC regulations require that licensees of nuclear generating facilities demonstrate reasonable assurance that sufficient funds will be available in certain minimum amounts to decommission the facility. These NRC minimum funding levels are typically based upon the assumption that decommissioning activities will commence after the end of the current licensed life of each unit. If a unit fails the NRC minimum funding test, then the plant’s owners or parent companies would be required to take steps, such as providing financial guarantees through letters of credit or parent company guarantees or making additional cash contributions to the NDT fund to ensure sufficient funds are available. See Note 8 — Nuclear Decommissioning of the Combined Notes to Consolidated Financial Statements for additional information.

If a nuclear plant were to early retire there is a risk that it will no longer meet the NRC minimum funding requirements due to the earlier commencement of decommissioning activities and a shorter time period over which the NDT funds could appreciate in value. A shortfall could require that Generation address the shortfall by providing additional financial assurances such as letters of credit or parent company guarantees for Generation’s share of the funding assurance. However, the amount of any guarantees or other assurance will ultimately depend on the decommissioning approach, the associated level of costs, and the NDT fund investment performance going forward. No later than two years after shutting down a plant, Generation must submit a PSDAR to the NRC that includes the planned option for decommissioning the site. Upon early retirement, Dresden will have adequate funding assurance, however, due to the earlier commencement of decommissioning activities and a shorter time period over which the NDT fund investments could appreciate in value, Byron may no longer meet the NRC minimum funding requirements and, as a result, additional financial assurance may be required. Considering the different approaches to decommissioning available to Generation, the most likely estimates currently anticipated could require financial assurance for radiological decommissioning at Byron of up to $55 million.

Upon issuance of any required financial guarantees, each site would be able to utilize the respective NDT funds for radiological decommissioning costs, which represent the majority of the total expected decommissioning costs. However, under the regulations, the NRC must approve an exemption in order for Generation to utilize the

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NDT funds to pay for non-radiological decommissioning costs (i.e. spent fuel management and site restoration costs, if applicable). If a unit does not receive this exemption, those costs would be borne by Generation without reimbursement from or access to the NDT funds. Based on current projections of the most likely decommissioning approach and expected exemptions from the NRC, it is expected that Dresden would not require supplemental cash from Generation, but some portion of the Byron spent fuel management costs would need to be funded through supplemental cash from Generation. While the ultimate amounts may vary and could be offset by reimbursement of certain spent fuel management costs under the DOE settlement agreement, decommissioning for Byron may require supplemental cash from Generation of up to $180 million, net of taxes, over a period of 10 years after permanent shutdown.

As of March 31, 2021, Generation is not required to provide any additional financial assurances for TMI Unit 1 under the SAFSTOR scenario which is the planned decommissioning option as described in the TMI Unit 1 PSDAR filed by Generation with the NRC on April 5, 2019. On October 16, 2019, the NRC granted Generation's exemption request to use the TMI Unit 1 NDT funds for spent fuel management costs. An additional exemption request would be required to allow the funds to be spent on site restoration costs, which are not expected to be incurred in the near term.

Project Financing (Exelon and Generation)

Project financing is used to help mitigate risk of specific generating assets. Project financing is based upon a nonrecourse financial structure, in which project debt is paid back from the cash generated by the specific asset or portfolio of assets. Borrowings under these agreements are secured by the assets and equity of each respective project. The lenders do not have recourse against Exelon or Generation in the event of a default. If a specific project financing entity does not maintain compliance with its specific debt financing covenants, there could be a requirement to accelerate repayment of the associated debt or other project-related borrowings earlier than the stated maturity dates. In these instances, if such repayment was not satisfied, or restructured, the lenders or security holders would generally have rights to foreclose against the project-specific assets and related collateral. The potential requirement to satisfy its associated debt or other borrowings earlier than otherwise anticipated could lead to impairments due to a higher likelihood of disposing of the respective project-specific assets significantly before the end of their useful lives. Additionally, project finance has credit facilities. Refer to Note 17 — Debt and Credit Agreements of the Exelon 2020 Form 10-K for additional information on credit facilities and nonrecourse debt.

Cash Flows from Operating Activities (All Registrants)

Generation’s cash flows from operating activities primarily result from the sale of electric energy and energy-related products and services to customers. Generation’s future cash flows from operating activities may be affected by future demand for and market prices of energy and its ability to continue to produce and supply power at competitive costs as well as to obtain collections from customers and the sale of certain receivables.

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 and Note 19 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements of the Exelon 2020 Form 10-K 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 three months ended March 31, 2021 and 2020 by Registrant:

Decrease in cash flows from operating activities	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Net income	$	(640)	$	(608)	$	29	$	27	$	28	$	20	$	7	$	11	$	1
Adjustments to reconcile net income to cash:
Non-cash operating activities	(484)		(391)		15		(6)		(18)		(8)		(1)		4		(7)
Pension and non-pension postretirement benefit contributions	(6)		27		(28)		—		(1)		(9)		(1)		—		(1)
Income taxes	169		3		(16)		(11)		(16)		(12)		(4)		(4)		(1)
Changes in working capital and other noncurrent assets and liabilities	(1,728)		(1,609)		(50)		(30)		(136)		(14)		(14)		(11)		6
Option premiums received (paid), net	54		54		—		—		—		—		—		—		—
Collateral received (posted), net	294		292		2		—		—		—		—		—		—
Decrease in cash flows from operating activities	$	(2,341)	$	(2,232)	$	(48)	$	(20)	$	(143)	$	(23)	$	(13)	$	—	$	(2)

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. In addition, significant operating cash flow impacts for the Registrants for the three months ended March 31, 2021 and 2020 were as follows:

•See Note 17 — Supplemental Financial Information of the Combined Notes to Consolidated Financial Statements and the Registrants’ Consolidated Statement of Cash Flows for additional information on non-cash operating activities.

•See Note 9 — Income Taxes of the Combined Notes to Consolidated Financial Statements and the Registrants' Consolidated Statement of Cash Flows for additional information on income taxes.

•Changes in working capital and other noncurrent assets and liabilities are primarily due to impacts resulting from the sale of customer accounts receivable at Exelon and Generation. See Note 6 – Accounts Receivable for additional information.

•Depending upon whether Generation is in a net mark-to-market liability or asset position, collateral may be required to be posted with or collected from its counterparties. In addition, the collateral posting and collection requirements differ depending on whether the transactions are on an exchange or in the over-the-counter markets.

Cash Flows from Investing Activities (All Registrants)

The following table provides a summary of the change in cash flows from investing activities for the three months ended March 31, 2021 and 2020 by Registrant:

Increase (decrease) in cash flows from investing activities	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Capital expenditures	$	(124)	$	176	$	(107)	$	(36)	$	(53)	$	(80)	$	(40)	$	(17)	$	(22)
Proceeds from NDT fund sales, net	20		20		—		—		—		—		—		—		—
Proceeds from sales of assets and businesses	680		680		—		—		—		—		—		—		—
Changes in intercompany money pool	—		254		—		(26)		—		—		114		—		—
Collection of DPP	1,574		1,574		—		—		—		—		—		—		—
Other investing activities	20		6		2		—		8		—		5		4		(6)
Increase (decrease) in cash flows from investing activities	$	2,170	$	2,710	$	(105)	$	(62)	$	(45)	$	(80)	$	79	$	(13)	$	(28)

Significant investing cash flow impacts for the Registrants for three months ended March 31, 2021 and 2020 were as follows:

•Variances in capital expenditures are primarily due to the timing of cash expenditures for capital projects. Refer to Liquidity and Capital Resources of the Exelon 2020 Form 10-K for additional information on projected capital expenditure spending.

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•See Note 2 – Mergers, Acquisitions, and Dispositions of the Combined Notes to Consolidated Financial Statements for additional information related to the sale of a significant portion of Generation's solar business.

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

•See Note 6 – Accounts Receivable of the Combined Notes to Consolidated Financial Statements for additional information on the Collection of DPP.

Capital Expenditure Spending

As of March 31, 2021, there have been no material changes to the Registrants' projected capital expenditures as disclosed in Liquidity and Capital Resources of the Exelon 2020 Form 10-K.

Cash Flows from Financing Activities (All Registrants)

The following table provides a summary of the change in cash flows from financing activities for the three months ended March 31, 2021 and 2020 by Registrant:

Increase (decrease) in cash flows from financing activities	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Changes in short-term borrowings, net	$	488	$	222	$	(58)	$	—	$	90	$	(268)	$	47	$	(144)	$	(171)
Long-term debt, net	6		(508)		(300)		375		—		437		—		125		311
Changes in intercompany money pool	—		(285)		—		(40)		—		(4)		—		(37)		(77)
Dividends paid on common stock	(1)		—		(2)		—		(12)		—		—		12		9
Distributions to member	—		10		—		—		—		53		—		—		—
Contributions from parent/member	—		—		73		(231)		—		416		1		114		302
Other financing activities	(24)		(4)		4		(4)		—		(4)		—		(2)		(3)
Increase (decrease) in cash flows from financing activities	$	469	$	(565)	$	(283)	$	100	$	78	$	630	$	48	$	68	$	371

Significant financing cash flow impacts for the Registrants for the three months ended March 31, 2021 and 2020 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 12 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on short-term borrowings.

•Long-term debt, net, varies due to debt issuances and redemptions each year. Refer to 12 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on debt issuances. Refer to debt redemptions tables below for additional information.

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

•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 19 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements of the Exelon 2020 Form 10-K for additional information on dividend restrictions. See below for quarterly dividends declared.

•For the three months ended March 31, 2021, other financing activities primarily consists of debt issuance costs. See Note 12 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information of the Registrants’ debt issuances.

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Debt

See Note 12 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on the Registrants’ debt issuances.

During the three months ended March 31, 2021, the following long-term debt was retired and/or redeemed:

Company(a)	Type	Interest Rate		Maturity	Amount
Generation	Continental Wind Nonrecourse Debt(b)	6.00	%	February 28, 2033	$	19
Generation	SolGen Nonrecourse Debt(b)	3.93	%	September 30, 2036	6
Generation	Antelope Valley DOE Nonrecourse Debt(b)	2.29 % - 3.56 %		January 5, 2037	5
Generation	RPG Nonrecourse Debt(b)	4.11	%	March 31, 2035	3
Generation	EGR IV Nonrecourse Debt(b)	3 month LIBOR + 2.75 %		December 15, 2027	2
ACE	Tax-Exempt First Mortgage Bonds	6.80	%	March 1, 2021	39
ACE	Transition Bonds	5.55	%	October 20, 2021	5

_________

(a)On April 15, 2021, Exelon Corporate redeemed $300 million of 2.45% senior notes. On April 1, 2021, ACE redeemed $200 million of 4.35% first mortgage bonds.

(b)See Note 17 — Debt and Credit Agreements of the Exelon 2020 Form 10-K for additional information on nonrecourse debt.

Dividends

Quarterly dividends declared by the Exelon Board of Directors during the three months ended March 31, 2021 and for the second quarter of 2021 were as follows:

Period	Declaration Date	Shareholder of Record Date	Dividend Payable Date	Cash per Share(a)
First Quarter 2021	February 21, 2021	March 8, 2021	March 15, 2021	$	0.3825
Second Quarter 2021	April 27, 2021	May 14, 2021	June 10, 2021	$	0.3825

_________

(a)Exelon's Board of Directors approved an updated dividend policy for 2021. The 2021 quarterly dividend will remain the same as the 2020 dividend of $0.3825 per share.

Credit Matters (All Registrants)

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 $10.6 billion in aggregate total commitments of which $6.9 billion was available to support additional commercial paper as of March 31, 2021, and of which no financial institution has more than 7% 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 first quarter of 2021 to fund their short-term liquidity needs, when necessary. Generation used its available credit facilities to manage short-term liquidity needs as a result of the impacts of the February 2021 extreme cold weather event and continues to believe it has sufficient cash on hand and available capacity on its revolver to meet its liquidity requirements. The Registrants routinely review the sufficiency of their liquidity position, including appropriate sizing of credit facility commitments, by performing various stress test scenarios, such as commodity price movements, increases in margin-related transactions, changes in hedging levels, and the impacts of hypothetical credit downgrades. The Registrants have continued to closely monitor events in the financial markets and the financial institutions associated with the credit facilities, including monitoring credit ratings and outlooks, credit default swap levels, capital raising, and merger activity. See PART I. ITEM 1A. RISK FACTORS of the Exelon 2020 Form 10-K for additional information regarding the effects of uncertainty in the capital and credit markets.

The Registrants believe their cash flow from operating activities, access to credit markets, and their credit facilities provide sufficient liquidity. If Generation lost its investment grade credit rating as of March 31, 2021, it would have been required to provide incremental collateral of approximately $1.4 billion to meet collateral obligations for derivatives, non-derivatives, normal purchases and normal sales contracts, and applicable

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payables and receivables, net of the contractual right of offset under master netting agreements, which is well within the $3.5 billion of available credit capacity of its revolver.

The following table presents the incremental collateral that each Utility Registrant would have been required to provide in the event each Utility Registrant lost its investment grade credit rating at March 31, 2021 and available credit facility capacity prior to any incremental collateral at March 31, 2021:

	PJM Credit Policy Collateral		Other Incremental Collateral Required(a)		Available Credit Facility Capacity Prior to Any Incremental Collateral
ComEd	$	20	$	—	$	863
PECO	14		32		600
BGE	3		48		444
Pepco	3		—		300
DPL	3		12		300
ACE	—		—		300

_________

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

Exelon Credit Facilities

Exelon Corporate, ComEd, and BGE meet their short-term liquidity requirements primarily through the issuance of commercial paper. Generation and PECO meet their short-term liquidity requirements primarily through the issuance of commercial paper and borrowings from the Exelon intercompany money pool. 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 12 — Debt and Credit Agreements of the Combined Notes to Consolidated Financial Statements for additional information on the Registrants’ short-term borrowing activity. See Note 17 — Debt and Credit Agreements of the Exelon 2020 Form 10-K for additional information on the Registrants’ credit facilities.

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 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information on collateral provisions.

The credit ratings for Exelon Corporate and the Utility Registrants did not change for the three months ended March 31, 2021. On February 24, 2021, S&P lowered Generation's senior unsecured debt rating to 'BBB-' from 'BBB'.

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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. The PHI intercompany money pool had no activity for the three months ended March 31, 2021. Maximum amounts contributed to and borrowed from the money pool by participant and the net contribution or borrowing as of March 31, 2021, are presented in the following table:

	During the Three Months Ended March 31, 2021				As of March 31, 2021
Exelon Intercompany Money Pool	Maximum Contributed		Maximum Borrowed		Contributed (Borrowed)
Exelon Corporate	$	735	$	—	$	267
Generation	—		(426)		—
PECO	135		(100)		48
BSC	—		(432)		(346)
PHI Corporate	—		(40)		(24)
PCI	60		—		55

Shelf Registration Statements

Exelon, Generation, 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 March 31, 2021
	Short-term Financing Authority(a)				Remaining Long-term Financing Authority(a)
	Commission	Expiration Date	Amount		Commission	Expiration Date	Amount
ComEd(b)	FERC	December 31, 2021	$	2,500	ICC	2023 & 2024	$	543
PECO	FERC	December 31, 2021	1,500		PAPUC	December 31, 2021	850
BGE	FERC	December 31, 2021	700		MDPSC	N/A	1,100
Pepco	FERC	December 31, 2021	500		MDPSC / DCPSC	December 31, 2022	750
DPL	FERC	December 31, 2021	500		MDPSC / DPSC	December 31, 2022	172
ACE	NJBPU	December 31, 2021	350		NJBPU	December 31, 2022	250

_________

(a)Generation currently has blanket financing authority it received from FERC in connection with its market-based rate authority.

(b)ComEd had $350 million available in long-term debt refinancing authority and $193 million available in new money long-term debt financing authority from the ICC as of March 31, 2021 and has an expiration date of February 1, 2024 and February 1, 2023, respectively.

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Contractual Obligations and Off-Balance Sheet Arrangements

Contractual obligations represent cash obligations that are considered to be firm commitments and commercial commitments triggered by future events. See Note 14 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for additional information.

Generation, ComEd, PECO, BGE, Pepco, DPL, and ACE have obligations related to contracts for the purchase of power and fuel supplies, and ComEd and PECO have obligations related to their financing trusts. The power and fuel purchase contracts and the financing trusts have been considered for consolidation in the Registrants’ respective financial statements pursuant to the authoritative guidance for VIEs. See Note 1 — Significant Accounting Policies of the Combined Notes to Consolidated Financial Statements in the Exelon 2020 Form 10-K for additional information.

For an in-depth discussion of the Registrants' contractual obligations and off-balance sheet arrangements, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Contractual Obligations and Off-Balance Sheet Arrangements” in the Exelon 2020 Form 10-K and Note 6 — Accounts Receivable of the Combined Notes to Consolidated Financial Statements.

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ITEM 3.    QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

The Registrants are exposed to market risks associated with adverse changes in commodity prices, counterparty credit, interest rates, and equity prices. Exelon’s RMC approves risk management policies and objectives for risk assessment, control and valuation, counterparty credit approval, and the monitoring and reporting of risk exposures. The RMC is chaired by the chief executive officer and includes the chief risk officer, chief strategy officer, chief executive officer of Exelon Utilities, chief commercial officer, chief financial officer, and chief executive officer of Constellation. The RMC reports to the Finance and Risk Committee of the Exelon Board of Directors on the scope of the risk management activities. The following discussion serves as an update to ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK of Exelon’s 2020 Annual Report on Form 10-K incorporated herein by reference.

Commodity Price Risk (All Registrants)

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 generates and 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, fossil fuel, and other commodities.

Generation

Electricity available from Generation’s owned or contracted generation supply in excess of Generation’s obligations to customers, including portions of the Utility Registrants' retail load, is sold into the wholesale markets. To reduce commodity price risk caused by market fluctuations, Generation enters into non-derivative contracts as well as derivative contracts, including swaps, futures, forwards, and options, with approved counterparties to hedge anticipated exposures. Generation uses derivative instruments as economic hedges to mitigate exposure to fluctuations in commodity prices. Generation expects the settlement of the majority of its economic hedges will occur during 2021 through 2023.

As of March 31, 2021, the percentage of expected generation hedged for the Mid-Atlantic, Midwest, New York, and ERCOT reportable segments is 94%-97% for 2021. Market price risk exposure is the risk of a change in the value of unhedged positions. The forecasted market price risk exposure for Generation’s entire economic hedge portfolio associated with a $5 reduction in the annual average around-the-clock energy price based on March 31, 2021 market conditions and hedged position would be an increase in pre-tax net income of approximately $31 million for 2021. See Note 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information.

Fuel Procurement

Approximately 60% of Generation’s uranium concentrate requirements from 2021 through 2025 are supplied by three suppliers. In the event of non-performance by these or other suppliers, Generation believes that replacement uranium concentrates can be obtained, although at prices that may be unfavorable when compared to the prices under the current supply agreements. Non-performance by these counterparties could have a material adverse impact on Exelon’s and Generation’s financial statements.

Utility Registrants

There have been no significant changes or additions to the Utility Registrants exposures to commodity price risk that were described in ITEM 1A. RISK FACTORS of Exelon’s 2020 Annual Report on Form 10-K. See Note 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information regarding commodity price risk exposure.

Trading and Non-Trading Marketing Activities

The following table detailing Exelon’s, Generation’s, and ComEd’s trading and non-trading marketing activities are included to address the recommended disclosures by the energy industry’s Committee of Chief Risk Officers (CCRO).

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The following table provides detail on changes in Exelon’s, Generation’s, and ComEd’s commodity mark-to-market net asset or liability balance sheet position from December 31, 2020 to March 31, 2021. It indicates the drivers behind changes in the balance sheet amounts. This table incorporates the mark-to-market activities that are immediately recorded in earnings. This table excludes all NPNS contracts and does not segregate proprietary trading activity. See Note 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information on the balance sheet classification of the mark-to-market energy contract net assets (liabilities) recorded as of March 31, 2021 and December 31, 2020.

	Exelon		Generation		ComEd
Total mark-to-market energy contract net assets (liabilities) at December 31, 2020(a)	$	428	$	729	$	(301)
Total change in fair value during 2021 of contracts recorded in results of operations	243		243		—
Reclassification to realized at settlement of contracts recorded in results of operations	(61)		(61)		—
Changes in fair value — recorded through regulatory assets(b)	6		—		6
Changes in allocated collateral	(270)		(270)		—
Net option premium paid	(16)		(16)		—
Option premium amortization	(17)		(17)		—
Upfront payments and amortizations(c)	(128)		(128)		—
Total mark-to-market energy contract net assets (liabilities) at March 31, 2021(a)	$	185	$	480	$	(295)

_________

(a)Amounts are shown net of collateral paid to and received from counterparties.

(b)For ComEd, the changes in fair value are recorded as a change in regulatory assets. As of March 31, 2021, ComEd recorded a regulatory asset of $295 million related to its mark-to-market derivative liabilities with unaffiliated suppliers. For the three months ended March 31, 2021, ComEd recorded $2 million of decreases in fair value and an increase for realized losses due to settlements of $8 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers.

(c)Includes derivative contracts acquired or sold by Generation through upfront payments or receipts of cash, excluding option premiums, and the associated amortizations.

Fair Values

The following tables present maturity and source of fair value for Exelon, Generation, and ComEd mark-to-market commodity contract net assets (liabilities). The tables provide two fundamental pieces of information. First, the tables provide the source of fair value used in determining the carrying amount of the Registrants’ total mark-to-market net assets (liabilities), net of allocated collateral. Second, the tables show the maturity, by year, of the Registrants’ commodity contract net assets (liabilities), net of allocated collateral, giving an indication of when these mark-to-market amounts will settle and either generate or require cash. See Note 13 — 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.

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Exelon

	Maturities Within												Total Fair Value
	2021		2022		2023		2024		2025		2026 and Beyond
Normal Operations, Commodity derivative contracts(a)(b):
Actively quoted prices (Level 1)	$	(27)	$	(6)	$	14	$	16	$	18	$	—	$	15
Prices provided by external sources (Level 2)	138		103		17		(1)		1		—		258
Prices based on model or other valuation methods (Level 3)(c)	(53)		95		42		(11)		(13)		(148)		(88)
Total	$	58	$	192	$	73	$	4	$	6	$	(148)	$	185

_________

(a)Mark-to-market gains and losses on other economic hedge and trading derivative contracts that are recorded in results of operations.

(b)Amounts are shown net of collateral paid to and received from counterparties (and offset against mark-to-market assets and liabilities) of $169 million at March 31, 2021.

(c)Includes ComEd’s net assets (liabilities) associated with the floating-to-fixed energy swap contracts with unaffiliated suppliers.

Generation

	Maturities Within												Total Fair Value
	2021		2022		2023		2024		2025		2026 and Beyond
Normal Operations, Commodity derivative contracts(a)(b):
Actively quoted prices (Level 1)	$	(27)	$	(6)	$	14	$	16	$	18	$	—	$	15
Prices provided by external sources (Level 2)	138		103		17		(1)		1		—		258
Prices based on model or other valuation methods (Level 3)	(29)		124		71		17		15		9		207
Total	$	82	$	221	$	102	$	32	$	34	$	9	$	480

_________

(a)Mark-to-market gains and losses on other economic hedge and trading derivative contracts that are recorded in the results of operations.

(b)Amounts are shown net of collateral paid to and received from counterparties (and offset against mark-to-market assets and liabilities) of $169 million at March 31, 2021.

ComEd

	Maturities Within												Total Fair Value
	2021		2022		2023		2024		2025		2026 and Beyond
Commodity derivative contracts(a):
Prices based on model or other valuation methods (Level 3)(a)	$	(24)	$	(29)	$	(29)	$	(28)	$	(28)	$	(157)	$	(295)

_________

(a)Represents ComEd’s net liabilities associated with the floating-to-fixed energy swap contracts with unaffiliated suppliers.

Credit Risk (All Registrants)

The Registrants would be exposed to credit-related losses in the event of non-performance by counterparties that execute derivative instruments. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date. See Note 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for detailed discussion of credit risk.

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Generation

The following tables provide information on Generation’s credit exposure for all derivative instruments, normal purchases and normal sales agreements, and payables and receivables, net of collateral and instruments that are subject to master netting agreements, as of March 31, 2021. The tables further delineate that exposure by credit rating of the counterparties and provide guidance on the concentration of credit risk to individual counterparties and an indication of the duration of a company’s credit risk by credit rating of the counterparties. The amounts in the tables below exclude credit risk exposure from individual retail customers, uranium procurement contracts, and exposure through RTOs, ISOs, and commodity exchanges, which are discussed below.

Rating as of March 31, 2021	Total  Exposure Before Credit Collateral		Credit Collateral(a)		Net Exposure		Number of Counterparties Greater than 10% of Net Exposure	Net Exposure of Counterparties Greater than 10% of Net Exposure
Investment grade	$	431	$	31	$	400	—	$	—
Non-investment grade	43		4		39
No external ratings
Internally rated — investment grade	146		1		145
Internally rated — non-investment grade	70		25		45
Total	$	690	$	61	$	629	—	$	—

	Maturity of Credit Risk Exposure
Rating as of March 31, 2021	Less than 2 Years		2-5 Years		Exposure Greater than 5 Years		Total Exposure Before Credit Collateral
Investment grade	$	332	$	52	$	47	$	431
Non-investment grade	43		—		—		43
No external ratings
Internally rated — investment grade	109		25		12		146
Internally rated — non-investment grade	48		16		6		70
Total	$	532	$	93	$	65	$	690

Net Credit Exposure by Type of Counterparty	As of March 31, 2021
Investor-owned utilities, marketers, power producers	$	451
Energy cooperatives and municipalities	123
Other	55
Total	$	629

_________

(a)As of March 31, 2021, credit collateral held from counterparties where Generation had credit exposure included $32 million of cash and $29 million of letters of credit.

The Utility Registrants

There have been no significant changes or additions to the Utility Registrants exposures to credit risk that are described in ITEM 1A. RISK FACTORS of Exelon’s 2020 Annual Report on Form 10-K. See Note 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information regarding credit exposure to suppliers.

Credit-Risk-Related Contingent Features (All Registrants)

Generation

As part of the normal course of business, Generation routinely enters into physical or financial contracts for the sale and purchase of electricity, natural gas, and other commodities. In accordance with the contracts and

165

applicable law, if Generation is downgraded by a credit rating agency, especially if such downgrade is to a level below investment grade, 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. Depending on Generation’s net position with a counterparty, the demand could be for the posting of collateral. In the absence of expressly agreed-to provisions that specify the collateral that must be provided, collateral requested will be a function of the facts and circumstances of the situation at the time of the demand. See Note 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information regarding collateral requirements. See Note 14 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements for additional information regarding the letters of credit supporting the cash collateral.

Generation transacts output through bilateral contracts. The bilateral contracts are subject to credit risk, which relates to the ability of counterparties to meet their contractual payment obligations. Any failure to collect these payments from counterparties could have a material impact on Exelon’s and Generation’s financial statements. As market prices rise above or fall below contracted price levels, Generation is required to post collateral with purchasers; as market prices fall below contracted price levels, counterparties are required to post collateral with Generation. To post collateral, Generation depends on access to bank credit facilities, which serve as liquidity sources to fund collateral requirements. See Note 17 — Debt and Credit Agreements of Exelon’s 2020 Annual Report on Form 10-K for additional information.

Utility Registrants

As of March 31, 2021, the Utility Registrants were not required to post collateral under their energy and/or natural gas procurement contracts. See Note 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information.

Interest Rate and Foreign Exchange Risk (Exelon and Generation)

Exelon and Generation use a combination of fixed-rate and variable-rate debt to manage interest rate exposure. Exelon and Generation may also utilize interest rate swaps to manage their interest rate exposure. A hypothetical 50 basis point increase in the interest rates associated with unhedged variable-rate debt (excluding Commercial Paper) and fixed-to-floating swaps would result in an immaterial decrease in Exelon pre-tax income for the three months ended March 31, 2021. To manage foreign exchange rate exposure associated with international energy purchases in currencies other than U.S. dollars, Generation utilizes foreign currency derivatives, which are typically designated as economic hedges. See Note 11 — Derivative Financial Instruments of the Combined Notes to Consolidated Financial Statements for additional information.

Equity Price Risk (Exelon and Generation)

Exelon and Generation maintain trust funds, as required by the NRC, to fund certain costs of decommissioning its nuclear plants. As of March 31, 2021, Generation’s NDT funds are reflected at fair value in its Consolidated Balance Sheets. The mix of securities in the trust funds is designed to provide returns to be used to fund decommissioning and to compensate Generation for inflationary increases in decommissioning costs; however, the equity securities in the trust funds are exposed to price fluctuations in equity markets, and the value of fixed-rate, fixed-income securities are exposed to changes in interest rates. Generation actively monitors the investment performance of the trust funds and periodically reviews asset allocation in accordance with Generation’s NDT fund investment policy. A hypothetical 25 basis points increase in interest rates and 10% decrease in equity prices would result in a $844 million reduction in the fair value of the trust assets. This calculation holds all other variables constant and assumes only the discussed changes in interest rates and equity prices.

ITEM 4.    CONTROLS AND PROCEDURES

During the first quarter of 2021, 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 Exelon’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

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information is recorded, processed, summarized, evaluated, and reported, as applicable, within the time periods specified in the SEC’s rules and forms. Due to the inherent limitations of control systems, not all misstatements may be detected. These inherent limitations include the realities that judgments in decision-making can be faulty and that breakdowns can occur because of simple error or mistake. Additionally, controls could be circumvented by the individual acts of some persons or by collusion of two or more people.

Accordingly, as of March 31, 2021, 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 first quarter of 2021 that materially affected, or are reasonably likely to materially affect, any of the Registrants' internal control over financial reporting.

PART II — OTHER INFORMATION

ITEM 1.    LEGAL PROCEEDINGS

The Registrants are parties to various lawsuits and regulatory proceedings in the ordinary course of their respective businesses. For information regarding material lawsuits and proceedings, see (a) ITEM 3. LEGAL PROCEEDINGS of Exelon’s 2020 Form 10-K and (b) Notes 3 — Regulatory Matters and 14 — Commitments and Contingencies of the Combined Notes to Consolidated Financial Statements in PART I, ITEM 1. FINANCIAL STATEMENTS of this Report. Such descriptions are incorporated herein by these references.

ITEM 1A.    RISK FACTORS

Risks Related to All Registrants

At March 31, 2021, the Registrants' risk factors were consistent with the risk factors described in the Registrants' combined 2020 Form 10-K in ITEM 1A. RISK FACTORS.

ITEM 4.    MINE SAFETY DISCLOSURES

All Registrants

Not applicable to the Registrants.

ITEM 5.    OTHER INFORMATION

All Registrants

None.

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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
4.1	One Hundred and Nineteenth Supplemental Indenture, dated as of February 15, 2021 from PECO to U.S. Bank National Association, as trustee (File No. 000-16844, Form 8-K dated March 8, 2021, Exhibit 4.1)
4.2	Supplemental Indenture, dated as of February 16, 2021, from ComEd to BNY Mellon Trust Company of Illinois, as trustee, and D.G. Donovan, as co-trustee (File No. 001-01839, Form 8-K dated March 9, 2021, Exhibit 4.1)
4.3	ACE Indenture Supplemental to Mortgage and Deed of Trust, dated as of February 15, 2021 (File No. 001-03559, Form 8-K dated March 10, 2021, Exhibit 4.1)
4.4	DPL Supplemental Indenture to the Mortgage and Deed of Trust, dated as of February 15, 2021 (File No. 001-01405, Form 8-K dated March 30, 2021, Exhibit 4.2)
4.5	Pepco Supplemental Indenture to the Mortgage and Deed of Trust, dated as of February 15, 2021 (File No. 001-01072, Form 8-K dated March 30, 2021, Exhibit 4.4)
4.6*	One Hundred and Twenty-Eighth Supplemental Indenture, dated January 1, 2021, between DPL and the Bank of New York, as trustee
10.1	Amendment No. 2 to Receivables Purchase Agreement, dated as of March 29, 2021, among Constellation NewEnergy, Inc., as servicer, and NewEnergy Receivables LLC, as seller, MUFG Bank, LTD., as agent, the Conduits party thereto, the Financial Institutions party thereto and the Purchaser Agents party thereto (File No. 001-16169, Form 8-K, dated March 31, 2021, Exhibit 10.1)
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 March 31, 2021 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 Christopher M. Crane for Exelon Generation Company, LLC
31-4	Filed by Bryan P. Wright for Exelon Generation Company, LLC
31-5	Filed by Joseph Dominguez for Commonwealth Edison Company
31-6	Filed by Jeanne M. Jones for Commonwealth Edison Company
31-7	Filed by Michael A. Innocenzo for PECO Energy Company
31-8	Filed by Robert J. Stefani for PECO Energy Company
31-9	Filed by Carim V. Khouzami for Baltimore Gas and Electric Company
31-10	Filed by David M. Vahos for Baltimore Gas and Electric Company
31-11	Filed by David M. Velazquez for Pepco Holdings LLC
31-12	Filed by Phillip S. Barnett for Pepco Holdings LLC
31-13	Filed by David M. Velazquez for Potomac Electric Power Company
31-14	Filed by Phillip S. Barnett for Potomac Electric Power Company
31-15	Filed by David M. Velazquez for Delmarva Power & Light Company
31-16	Filed by Phillip S. Barnett for Delmarva Power & Light Company
31-17	Filed by David M. Velazquez for Atlantic City Electric Company
31-18	Filed by Phillip S. Barnett for Atlantic City Electric Company

169

Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes — Oxley Act of 2002) as to the Quarterly Report on Form 10-Q for the quarterly period ended March 31, 2021 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 Christopher M. Crane for Exelon Generation Company, LLC
32-4	Filed by Bryan P. Wright for Exelon Generation Company, LLC
32-5	Filed by Joseph Dominguez for Commonwealth Edison Company
32-6	Filed by Jeanne M. Jones for Commonwealth Edison Company
32-7	Filed by Michael A. Innocenzo for PECO Energy Company
32-8	Filed by Robert J. Stefani for PECO Energy Company
32-9	Filed by Carim V. Khouzami for Baltimore Gas and Electric Company
32-10	Filed by David M. Vahos for Baltimore Gas and Electric Company
32-11	Filed by David M. Velazquez for Pepco Holdings LLC
32-12	Filed by Phillip S. Barnett for Pepco Holdings LLC
32-13	Filed by David M. Velazquez for Potomac Electric Power Company
32-14	Filed by Phillip S. Barnett for Potomac Electric Power Company
32-15	Filed by David M. Velazquez for Delmarva Power & Light Company
32-16	Filed by Phillip S. Barnett for Delmarva Power & Light Company
32-17	Filed by David M. Velazquez for Atlantic City Electric Company
32-18	Filed by Phillip S. Barnett for Atlantic City Electric Company

170

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/    FABIAN E. SOUZA
Fabian E. Souza
Senior Vice President and Corporate Controller (Principal Accounting Officer)

May 5, 2021

171

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 GENERATION COMPANY, LLC

/s/    CHRISTOPHER M. CRANE	/s/    BRYAN P. WRIGHT
Christopher M. Crane	Bryan P. Wright
Principal Executive Officer	Senior Vice President and Chief Financial Officer (Principal Financial Officer)
/s/    MATTHEW N. BAUER
Matthew N. Bauer
Vice President and Controller (Principal Accounting Officer)

May 5, 2021

172

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/    JOSEPH DOMINGUEZ	/s/    JEANNE M. JONES
Joseph Dominguez	Jeanne M. Jones
Chief Executive Officer (Principal Executive Officer)	Senior Vice President, Chief Financial Officer and Treasurer (Principal Financial Officer)
/s/    STEVEN J. CICHOCKI
Steven J. Cichocki
Director, Accounting (Principal Accounting Officer)

May 5, 2021

173

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,Chief Executive Officer (Principal Executive Officer)	Senior Vice President, Chief Financial Officer and Treasurer (Principal Financial Officer)
/s/    CAROLINE FULGINITI
Caroline Fulginiti
Director, Accounting (Principal Accounting Officer)

May 5, 2021

174

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)

May 5, 2021

175

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/ DAVID M. VELAZQUEZ	/s/    PHILLIP S. BARNETT
David M. Velazquez	Phillip S. Barnett
President, Chief Executive Officer (Principal Executive Officer)	Senior Vice President, Chief Financial Officer and Treasurer (Principal Financial Officer)
/s/ JULIE E. GIESE
Julie E. Giese
Director, Accounting (Principal Accounting Officer)

May 5, 2021

176

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/ DAVID M. VELAZQUEZ	/s/    PHILLIP S. BARNETT
David M. Velazquez	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)

May 5, 2021

177

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/ DAVID M. VELAZQUEZ	/s/    PHILLIP S. BARNETT
David M. Velazquez	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)

May 5, 2021

178

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/ DAVID M. VELAZQUEZ	/s/    PHILLIP S. BARNETT
David M. Velazquez	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)

May 5, 2021

179

EX-4.6

                            This Instrument Prepared By:

/s/ Christie D. Cannon

Christie D. Cannon

                            Delmarva Power & Light Company

                            Mailstop 92DC42

                            500 N. Wakefield Drive

                            Newark, DE 19702-5440

DELMARVA POWER & LIGHT COMPANY

TO

THE BANK OF NEW YORK MELLON,

Trustee.

ONE HUNDRED AND TWENTY-EIGHTH SUPPLEMENTAL

INDENTURE

Dated as of January 1, 2021

(but executed on the dates shown on the execution page)

1

    This ONE HUNDRED AND TWENTY-EIGHTH SUPPLEMENTAL INDENTURE, dated as of the first day of January, 2021 (but executed on the dates hereinafter shown), made and entered into by and between DELMARVA POWER & LIGHT COMPANY, a corporation of the State of Delaware and the Commonwealth of Virginia, hereinafter called the Company and THE BANK OF NEW YORK MELLON, a New York banking corporation, hereinafter called the Trustee;

    WITNESSETH:

    WHEREAS, the Company heretofore executed and delivered its Indenture of Mortgage and Deed of Trust (hereinafter in this One Hundred and Twenty-Eighth Supplemental Indenture called the “Original Indenture”), dated as of October 1, 1943, to The New York Trust Company, a corporation of the State of New York, as Trustee, to which The Bank of New York Mellon is successor Trustee, to secure the First Mortgage Bonds of the Company, unlimited in aggregate principal amount and issuable in series, from time to time, in the manner and subject to the conditions set forth in the Original Indenture granted and conveyed unto the Trustee, upon the trusts, uses and purposes specifically therein set forth, certain real estate, franchises and other property therein described, including property acquired after the date thereof, except as therein otherwise provided; and

    WHEREAS, the Original Indenture has been supplemented by one hundred and twenty-six supplemental indentures specifically subjecting to the lien of the Original Indenture as though included in the granting clause thereof certain property in said supplemental indentures specifically described and amending and modifying the provisions of the Original Indenture (the Original Indenture, as amended, modified and supplemented by all of the indentures supplemental thereto, including this One Hundred and Twenty-Eighth Supplemental Indenture, is hereinafter in this One Hundred and Twenty-Eighth Supplemental Indenture called the “Indenture”); and

    WHEREAS, the execution and delivery of this One Hundred and Twenty-Eighth Supplemental Indenture has been duly authorized by Unanimous Written Consent of the Board of Directors of the Company, and all conditions and requirements necessary to make this One Hundred and Twenty-Eighth Supplemental Indenture a valid, binding and legal instrument in accordance with its terms, for the purposes herein expressed, and the execution and delivery hereof, have been in all respects duly authorized; and

    WHEREAS, it is provided in and by the Original Indenture, inter alia, as follows:

    “IT IS HEREBY AGREED by the Company that all the property, rights and franchises acquired by the Company after the date hereof (except any hereinbefore or hereinafter expressly excepted) shall (subject to the provisions of Section 9.01 hereof and to the extent permitted by law) be as fully embraced within the lien hereof as if such property, rights and franchises were now owned by the Company and/or specifically described herein and conveyed hereby;”

and

    WHEREAS, the Company has acquired certain other property, real, personal and mixed, which heretofore has not been specifically conveyed to the Trustee;

    NOW, THEREFORE, this ONE HUNDRED AND TWENTY-EIGHTH SUPPLEMENTAL INDENTURE WITNESSETH that for and in consideration of the premises and in pursuance of the provisions of the Indenture, the Company has granted, bargained, sold, released, conveyed, assigned, transferred, mortgaged, pledged, set over and confirmed, and granted a security interest therein, and by these presents does grant, bargain, sell, release, convey, assign, transfer, mortgage, pledge, set over and confirm, and grant a security interest therein, subject to the provisions of the Indenture, unto the Trustee and to its successors in the trust in the Indenture created, to its and their assigns forever, all the following described properties of the Company, and does confirm that the Company will not cause or consent to a partition, either voluntary or through legal proceedings, of property, whether herein described or heretofore or hereafter acquired, in which its ownership shall be as tenants in common, except as permitted by, and in conformity with, the provisions of the Indenture and particularly of Article IX thereof:

2

MARYLAND

Worcester County

Property Name	Instrument Date	Deed Records		Tax Map No.
		Liber	Folio
Ocean City Substation Purchase of 0.1148 acres of land located 105 St Louis Ave, Ocean City, MD 21842	12/10/2020	7875	0001	Tax Map 0110 Parcel 3953

Together with all other property, real, personal and mixed, tangible and intangible (except such property as in said Indenture expressly excepted from the lien and operation thereof), acquired by the Company on or prior to December 31, 2020, and not heretofore specifically subjected to the lien of the Indenture.

    Also without limitation of the generality of the foregoing, the easements and rights-of-way and other rights in or relating to real estate or the occupancy of the same owned by the Company, and whether used or not used in connection with the Company’s operations, which are conveyed to the Company and recorded in the following Real Property Deed Records to which reference is made for a more particular description, to wit:

DELAWARE

Kent County

Instrument Date	Deed Records		Tax ID No.
	Instrument No.
06/06/18	9966	47	7-00-11100-01-3800-00001
03/19/19	9968	232	4-00-04700-01-4100-00001
11/12/19	9968	236	3-12-01108-01-1300-00001
01/27/20	10568	329	7-20-09406-04-4100
04/02/20	10568	317	7-00-11200-01-0600-00001
06/01/20	10261	130	8-00-12800-01-4000-000
09/10/20	10568	325	7-02-08520-01-1000-00001
09/24/20	10568	321	7-00-10400-01--4206-00001
09/28/20	10568	313	7-00-10400-01--4205-00001
11/20/20	2020-402813		3-00-04600-02-2900-00001

3

DELAWARE

New Castle County

Instrument Date	Deed Records	Tax ID No.
09/25/18	20200427-0032737	18-036.00-001
03/15/19	20200427-0032736	10-049.00-073
05/13/19	20200424-0032384	12-027.00-112
07/02/19	20200629-0052919	07-028.40-008
07/02/19	20200629-0052920	07-028.40-033
07/24/19	20200629-0052918	07-028.40-007
10/25/19	20200110-0002868	26-043.40-203
10/25/19	20200110-0002869	26-043.40-051
10/28/19	202-00129-0008318	14-014.00-045
10/30/19	20200424-0032382	18-013.00-106
11/04/19	20200129-0008220	11-031.00-100
11/19/19	20200424-0032383	10-014.00-002
12/06/19	20200114-0003667	07-026.00-184
12/19/19	20200109-0002683	13-019.00-025 & others
12/19/19	20200109-0002684	11-030.20-002 & others
12/20/19	202-00221-0004537	14-022.00-014
12/31/19	20200122-0006059	13-017.00-148
12/31/19	20200133-0006060	13-017.00-147
01/15/20	20200414-0029065	26-043.10-276
01/15/20	20200414-0029066	26-043.10-272
01/23/20	202-00221-0004538	11-043.00-078
01/23/20	20201228-0118622	07-032.10-131
01/23/20	20201228-0118623	07-032.10-133
01/30/20	202-00221-0004539	12-013.00-007
02/06/20	20200629-0052888	10-033.30-026
02/21/20	20200629-0052917	06-098.00-006
03/04/20	20200313-0021028	10-010.20-165
03/18/20	20200424-0032385	07-042.20-661, 660, 099, 663
03/23/20	20200424-0032386	10-020.10-270
03/23/20	20200914-0078828	26-014.10-002
03/31/20	20200629-0052886	26-012.10-008, 013 to 017
03/31/20	20200629-0052887	18-013.00-198
05/07/20	20200611-0047411	09-018.00-045
05/22/20	20200914-0078829	07-023.00-002
06/08/20	20200708-005623	06-136.00-030
06/23/20	20200914-0078831	08-048.00-005
07/23/20	20201015-0090595	13-012.00-139
07/23/20	20201015-0090596	13-012.00-140
07/28/20	20200914-0078830	07-042.10-143
08/13/20	20200921-0081716	07-026.00-182
08/31/20	20201228-0118624	16-004.00-682
08/31/20	20201228-0118625	16-004.00-690

4

Instrument Date	Deed Records	Tax ID No.
09/16/20	20201026-0095095	07-037.20-235
10/06/20	20201105-0099408	10-048.00-001, 002, 003
10/15/20	20201228-0118626	11-028.00-026
12/14/20	20210121-0008763	09-029.00-012

DELAWARE

Sussex County

Instrument Date	Deed Records		Tax ID No.
	Book	Page
11/06/14	5216	267	334-10.00-30.26 &30.27
04/17/17	5217	9	233-5.00-117.00
10/23/19	5210	1	134-17.00-12.00
02/02/20	5210	42	334-5.00-168.14
02/14/20	5217	95	234-21.00-138.00
03/10/20	5228	248	334-23.06-10.00
03/11/20	5228	252	334-23.06-12.00
05/01/20	5233	190	533-18.00-66.01
05/19/20	5251	112	532-11.00-74.00, 74.01, 74.02
05/19/20	5251	63	532-11.00-74.03
05/20/20	5246	175	533-18.00-87.06
05/20/20	5246	173	533-18.00-86.00
05/20/20	5246	166	533-18.00-87.01
05/21/20	5246	179	532-13.00-79.08
08/21/20	5312	196	335-8.00-25.00
08/27/20	5307	221	134-10.00-62.13
09/26/20	5345	74	134-12.00-1026.00
10/16/20	5346	204	134-12.00-333.00
10/16/20	5346	201	134-12.00-334.00
10/19/20	5346	207	532-6.00-67.01
10/26/20	5384	145	334-19.00-170.03
12/15/20	5384	141	832-13.00-78.00

MARYLAND

Caroline County

Instrument Date	Deed Records		Tax Parcel
	Book	Page
02/21/20	1414	309	0168
08/17/20	1439	357	2012
09/08/20	1439	355	2012

5

MARYLAND

Cecil County

Instrument Date	Deed Records		Map	Parcel
	Book	Page
11/15/19	4542	314	0067	0017
01/03/20	4532	7	0031	0423
01/08/20	4535	319	0025	0453
01/16/20	4541	494	0304	2116
01/23/20	4548	343	0302	1140
02/13/20	4562	95	0002	0027
02/21/20	4569	398	0034	0012
02/22/20	4562	98	0695	0013
03/06/20	4569	405	0038	0386
03/07/20	4569	402	0037	0597
03/09/20	4566	247	0036	0366
03/18/20	4579	16	0013	0002
04/20/20	4592	485	0318	0463
05/08/20	4610	353	0062	0017
05/14/20	4617	233	0019	0531
06/26/20	4633	439	0032	0485
07/02/20	4642	214	0031	0231
07/08/20	4678	482	0031	0623
07/22/20	4658	230	0800	0682
07/25/20	4651	119	0035	0654
07/28/20	4658	226	0025	0801
07/29/20	4678	485	062C	0106
09/14/20	4698	464	031B	0536
09/21/20	4698	468	025H	0493
09/25/20	4706	221	0030	0018
09/25/20	4706	224	0030	0085
09/28/20	4706	227	0018	0381
10/14/20	4730	156	0036	0550
11/16/20	4749	322	0031	0667
11/16/20	4756	16	0031	0666

6

MARYLAND

Dorchester County

Instrument Date	Deed Records		Map	Parcel
	Liber	Folio
12/18/19	1557	201	0305	3780
01/06/20	1556	171	0034	0001
01/23/20	1562	172	0030	0282
02/05/20	1562	98	0305	3946
02/06/20	1574	407	0022	0120
02/28/20	1570	223	0035	0165
03/16/20	1571	72	0018	0040
07/26/20	1590	131	0500	0011
09/17/20	1598	30	0030	0002
10/16/20	1609	401	0017	0073
11/04/20	1613	403	0030	0250
11/20/20	1613	399	0301	4487
03/02/20	13750	399	0028	0256

MARYLAND

Harford County

Instrument Date	Deed Records		Map	Parcel
	Liber	Folio
03/02/20	13750	399	0028	0256

MARYLAND

Kent County

Instrument Date	Deed Records		Map	Parcel
	Liber	Folio
02/07/20	1045	295	0044	0115
02/21/20	1047	174	0203	1195
06/29/20	1086	240	0100	1575

MARYLAND

Queen Anne’s County

Instrument Date	Deed Records		Map	Parcel
	Liber	Folio
07/13/20	3403	283	0052	0012
10/29/20	3540	105	0054	0025

7

MARYLAND

Talbot County

Instrument Date	Deed Records		Map	Parcel
	Liber	Folio
01/07/20	2682	362	0047	0087 & 0124
01/21/20	2676	452	0055	0028
02/24/20	2687	50	0052	0032
02/24/20	2687	46	0059	0009
05/14/20	2706	497	0033	0031 & 0106
07/13/20	1112	44	0028	0324
09/01/20	1104	248	015F	0110
09/01/20	1104	252	072B	0297
09/01/20	1104	256	0032	0196

MARYLAND

Wicomico County

Instrument Date	Deed Records		Map	Parcel	Lot
	Liber	Folio
07/20/19	4669	91	0059	0032
01/24/20	4587	340	0104	1353
01/30/20	4593	84	0039	0421
02/05/20	4595	493	0031	0450
03/19/20	4616	80	0020	0153 & 0215
04/28/20	4632	97	0107	1066
04/30/20	4654	81	0104	1811	4 & 5
05/26/20	4640	228	0038	0001
06/01/20	4656	1	011A	0121	1, 2, 3, 4
06/03/20	4656	5	0063	0064
06/23/20	4658	140	0042	0044
08/19/20	4693	2	0041	0087
11/17/20	4749	477	0030	0271
11/17/20	4749	483	0030	0069	1A
11/30/20	4758	43	0020	0005	2
12/21/20	1117	1	0300	1728

8

MARYLAND

Worcester County

Instrument Date	Deed Records		Map	Parcel	Lot
	Liber	Folio
12/14/19	7582	188	0115	9962	F - 47
01/24/20	7599	62	0020	0190
03/19/20	7642	496	0009	0146
05/05/20	7768	140	0093	0052
06/22/20	7768	136	0019	0123	5
08/26/20	7799	108	0020	0108	2
08/26/20	7799	112	0020	0108	3
08/26/20	7799	116	0020	0108	4
09/08/20	7799	104	0026	0392
09/29/20	7892	85	0026	0258
10/09/20	7892	76	0100	0116
10/09/20	7892	93	0049	0114
10/09/20	7897	294	0063	0140
10/09/20	7897	303	0063	0140
10/29/20	7892	81	0010	0153
10/31/20	7892	89	0079	0215
11/11/20	7909	455	0401	0717
11/12/20	7897	299	0113	7975
11/30/20	7909	168	0009	0067	3

    The following is a schedule of bonds issued under the Eighty-Eighth Supplemental Indenture and Credit Line Deed of Trust, effective as of October 1, 1994, that can be designated as First Mortgage Bonds, Series I, which may also be designated as Secured Medium Term Notes, Series I; and First Mortgage Bonds, Pledged Series I.

First Mortgage Bonds, Series I/Secured Medium Term Notes, Series I
Issuance Date	Tranche	Maturity	Principal
06/19/95	7.71% Bonds	06/01/25	$100,000,000
06/19/95	6.95% Amortizing Bonds	06/01/08	$25,800,000
11/25/08	6.40% Bonds	12/01/13	$250,000,000
First Mortgage Bonds, Pledged Series I
Issuance Date	Tranche	Maturity	Principal
10/12/94	1994	10/01/29	$33,750,000
Total Bonds Issued:			$409,550,000

9

    As supplemented and amended by this One Hundred and Twenty-Eighth Supplemental Indenture, the Original Indenture and all indentures supplemental thereto are in all respects ratified and confirmed and the Original Indenture and the aforesaid supplemental indentures and this One Hundred and Twenty-Eighth Supplemental Indenture shall be read, taken and construed as one and the same instrument.

    This One Hundred and Twenty-Eighth Supplemental Indenture shall be simultaneously executed in several counterparts, and all such counterparts executed and delivered, each as an original, shall constitute but one and the same instrument.

    The recitals of fact contained herein shall be taken as the statements of the Company, and the Trustee assumes no responsibility for the correctness of the same.

    The debtor and its mailing address are Delmarva Power & Light Company, Mailstop 92DC42, 500 N. Wakefield Drive, Newark, Delaware 19702-5440. The secured party and its address, from which information concerning the security interest hereunder may be obtained, is The Bank of New York Mellon, 500 Ross Street, 12th Floor, Pittsburgh, Pennsylvania 15262, Attn: Corporate Trust Administration.

    The Company acknowledges that it received a true and correct copy of this One Hundred and Twenty-Eighth Supplemental Indenture.

    This One Hundred and Twenty-Eighth Supplemental Indenture is executed and delivered pursuant to the provisions of Section 5.11 and paragraph (a) of Section 17.01 of the Indenture for the purpose of conveying, transferring and assigning to the Trustee and of subjecting to the lien of the Indenture with the same force and effect as though included in the granting clause thereof the above described property so acquired by the Company on or prior to the date of execution, and not heretofore specifically subject to the lien of the Indenture; but nothing contained in this One Hundred and Twenty-Eighth Supplemental Indenture shall be deemed in any manner to affect (except for such purposes) or to impair the provisions, terms and conditions of the Original Indenture, or of any indenture supplemental thereto and the provisions, terms and conditions thereof are hereby expressly confirmed.

[Signatures on following pages]

10

IN WITNESS WHEREOF, each of the Company and the Trustee has caused this instrument to be signed in its name and behalf by an Authorized Officer, effective as of the 1st day of January, 2021.

DELMARVA POWER & LIGHT COMPANY

Date of Execution            By    /s/ Brian J. Buck            

March 29, 2021                Brian J. Buck

Authorized Officer

DISTRICT OF COLUMBIA    ) SS

    BE IT REMEMBERED that as of the 29th day of March, 2021, personally came before me, a notary public for the District of Columbia, Brian J. Buck, Authorized Officer of DELMARVA POWER & LIGHT COMPANY, a corporation of the State of Delaware and the Commonwealth of Virginia (the “Company”), party to the foregoing instrument, known to me personally to be such, and acknowledged the instrument to be his own act and deed and the act and deed of the Company; that his signature is in his own proper handwriting; and that his act of signing, executing and delivering such instrument was duly authorized by resolution of the Board of Directors of the Company.

    GIVEN under my hand and official seal the day and year aforesaid.

/s/ Dorothy Bonds                    

                Notary Public, District of Columbia

                My commission expires 10/14/2021.

11

THE BANK OF NEW YORK MELLON,

as Trustee

Date of Execution            By    /s/ Rita Duggan            

March 17, 2021                Rita Duggan

Vice President

STATE OF NEW YORK        )

    ) SS.

COUNTY OF NEW YORK    )

    BE IT REMEMBERED that as of the 17th day of March, 2021, personally came before me, a Notary Public for the State of New York, Rita Duggan, Vice President of THE BANK OF NEW YORK MELLON, a New York banking corporation (the “Trustee”), party to the foregoing instrument, known to me personally to be such, and acknowledged the instrument to be [his/her/their] own act and deed and the act and deed of the Trustee; that [his/her/their] signature is [his/her/their] own proper handwriting; and that his act of signing, executing and delivering said instrument was duly authorized by resolution of the Board of Directors of the Trustee.

    GIVEN under my hand and official seal the day and year aforesaid.

/s/ Rafal Bar                    

                Rafal Bar

                Notary Public, State of New York

                No. 01BA6293822

                Qualified Kings County

                Commission Expires January 31, 2022

12

CERTIFICATE OF RESIDENCE

    THE BANK OF NEW YORK MELLON, successor Trustee to the Trustee within named, hereby certifies that it has a residence at 240 Greenwich Street, in the Borough of Manhattan, in The City of New York, in the State of New York.

                THE BANK OF NEW YORK MELLON

                    By    /s/ Rita Duggan        

                        Rita Duggan

Vice President

13

Certification

    This document was prepared under the supervision of an attorney admitted to practice before the Court of Appeals of Maryland, or by or on behalf of one of the parties named in the within instrument.

/s/ Christie D. Cannon                

                    Christie D. Cannon

14

EX-31.1

Exhibit 31-1

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Christopher M. Crane, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Exelon Corporation;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    CHRISTOPHER M. CRANE

President and Chief Executive Officer

(Principal Executive Officer)

Date: May 5, 2021

EX-31.2

Exhibit 31-2

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Joseph Nigro, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Exelon Corporation;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    JOSEPH NIGRO

Senior Executive Vice President and Chief Financial Officer

(Principal Financial Officer)

Date: May 5, 2021

EX-31.3

Exhibit 31-3

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Christopher M. Crane, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Exelon Generation Company, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    CHRISTOPHER M. CRANE

Principal Executive Officer

Date: May 5, 2021

EX-31.4

Exhibit 31-4

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Bryan P. Wright, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Exelon Generation Company, LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    BRYAN P. WRIGHT

Senior Vice President and Chief Financial Officer

(Principal Financial Officer)

Date: May 5, 2021

EX-31.5

Exhibit 31-5

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Joseph Dominguez, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Commonwealth Edison Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    JOSEPH DOMINGUEZ

Chief Executive Officer
(Principal Executive Officer)

Date: May 5, 2021

EX-31.6

Exhibit 31-6

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Jeanne M. Jones, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Commonwealth Edison Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    JEANNE M. JONES

Senior Vice President, Chief Financial Officer and Treasurer

(Principal Financial Officer)

Date: May 5, 2021

EX-31.7

Exhibit 31-7

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Michael A. Innocenzo, certify that:

1.I have reviewed this quarterly report on Form 10-Q of PECO Energy Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    MICHAEL A. INNOCENZO

President and Chief Executive Officer

(Principal Executive Officer)

Date: May 5, 2021

EX-31.8

Exhibit 31-8

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Robert J. Stefani, certify that:

1.I have reviewed this quarterly report on Form 10-Q of PECO Energy Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    ROBERT J. STEFANI

Senior Vice President, Chief Financial Officer and Treasurer

(Principal Financial Officer)

Date: May 5, 2021

EX-31.9

Exhibit 31-9

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Carim V. Khouzami, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Baltimore Gas and Electric Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    CARIM V. KHOUZAMI

Chief Executive Officer

(Principal Executive Officer)

Date: May 5, 2021

EX-31.10

Exhibit 31-10

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, David M. Vahos, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Baltimore Gas and Electric Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    DAVID M. VAHOS

Senior Vice President, Chief Financial Officer
and Treasurer

(Principal Financial Officer)

Date: May 5, 2021

EX-31.11

Exhibit 31-11

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, David M. Velazquez, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Pepco Holdings LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    DAVID M. VELAZQUEZ

President and Chief Executive Officer

(Principal Executive Officer)

Date: May 5, 2021

EX-31.12

Exhibit 31-12

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Phillip S. Barnett, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Pepco Holdings LLC;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    PHILLIP S. BARNETT

Senior Vice President, Chief Financial Officer and Treasurer

(Principal Financial Officer)

Date: May 5, 2021

EX-31.13

Exhibit 31-13

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, David M. Velazquez, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Potomac Electric Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    DAVID M. VELAZQUEZ

President and Chief Executive Officer

(Principal Executive Officer)

Date: May 5, 2021

EX-31.14

Exhibit 31-14

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Phillip S. Barnett, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Potomac Electric Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    PHILLIP S. BARNETT

Senior Vice President, Chief Financial Officer and Treasurer

(Principal Financial Officer)

Date: May 5, 2021

EX-31.15

Exhibit 31-15

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, David M. Velazquez, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Delmarva Power & Light Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    DAVID M. VELAZQUEZ

President and Chief Executive Officer

(Principal Executive Officer)

Date: May 5, 2021

EX-31.16

Exhibit 31-16

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Phillip S. Barnett, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Delmarva Power & Light Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    PHILLIP S. BARNETT

Senior Vice President, Chief Financial Officer and Treasurer

(Principal Financial Officer)

Date: May 5, 2021

EX-31.17

Exhibit 31-17

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, David M. Velazquez, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Atlantic City Electric Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    DAVID M. VELAZQUEZ

President and Chief Executive Officer

(Principal Executive Officer)

Date: May 5, 2021

EX-31.18

Exhibit 31-18

CERTIFICATION PURSUANT TO RULE 13a-14(a) AND 15d-14(a) OF THE SECURITIES

AND EXCHANGE ACT OF 1934

I, Phillip S. Barnett, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Atlantic City Electric Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/    PHILLIP S. BARNETT

Senior Vice President, Chief Financial Officer and Treasurer

(Principal Financial Officer)

Date: May 5, 2021

EX-32.1

Exhibit 32-1

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Exelon Corporation for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Exelon Corporation.

/s/    CHRISTOPHER M. CRANE

Christopher M. Crane

President and Chief Executive Officer

Date: May 5, 2021

EX-32.2

Exhibit 32-2

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Exelon Corporation for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Exelon Corporation.

/s/    JOSEPH NIGRO

Joseph Nigro

Senior Executive Vice President and Chief Financial Officer

Date: May 5, 2021

EX-32.3

Exhibit 32-3

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Exelon Generation Company, LLC for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Exelon Generation Company, LLC.

/s/    CHRISTOPHER M. CRANE

Christopher M. Crane

Principal Executive Officer

Date: May 5, 2021

EX-32.4

Exhibit 32-4

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Exelon Generation Company, LLC for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Exelon Generation Company, LLC.

/s/    BRYAN P. WRIGHT

Bryan P. Wright

Senior Vice President and Chief Financial Officer

Date: May 5, 2021

EX-32.5

Exhibit 32-5

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Commonwealth Edison Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Commonwealth Edison Company.

/s/    JOSEPH DOMINGUEZ

Joseph Dominguez

Chief Executive Officer

Date: May 5, 2021

EX-32.6

Exhibit 32-6

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Commonwealth Edison Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Commonwealth Edison Company.

/s/    JEANNE M. JONES

Jeanne M. Jones

Senior Vice President, Chief Financial Officer and Treasurer

Date: May 5, 2021

EX-32.7

Exhibit 32-7

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of PECO Energy Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of PECO Energy Company.

/s/    MICHAEL A. INNOCENZO

Michael A. Innocenzo

President and Chief Executive Officer

Date: May 5, 2021

EX-32.8

Exhibit 32-8

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of PECO Energy Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of PECO Energy Company.

/s/    ROBERT J. STEFANI

Robert J. Stefani

Senior Vice President, Chief Financial Officer and Treasurer

Date: May 5, 2021

EX-32.9

Exhibit 32-9

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Baltimore Gas and Electric Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Baltimore Gas and Electric Company.

/s/    CARIM V. KHOUZAMI

Carim V. Khouzami

Chief Executive Officer

Date: May 5, 2021

EX-32.10

Exhibit 32-10

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Baltimore Gas and Electric Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Baltimore Gas and Electric Company.

/s/    DAVID M. VAHOS

David M. Vahos

Senior Vice President, Chief Financial Officer and Treasurer

Date: May 5, 2021

EX-32.11

Exhibit 32-11

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Pepco Holdings LLC for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Pepco Holdings LLC.

/s/    DAVID M. VELAZQUEZ

David M. Velazquez

President and Chief Executive Officer

Date: May 5, 2021

EX-32.12

Exhibit 32-12

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Pepco Holdings LLC for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Pepco Holdings LLC.

/s/    PHILLIP S. BARNETT

Phillip S. Barnett

Senior Vice President, Chief Financial Officer and Treasurer

Date: May 5, 2021

EX-32.13

Exhibit 32-13

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Potomac Electric Power Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Potomac Electric Power Company.

/s/    DAVID M. VELAZQUEZ

David M. Velazquez

President and Chief Executive Officer

Date: May 5, 2021

EX-32.14

Exhibit 32-14

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Potomac Electric Power Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Potomac Electric Power Company.

/s/    PHILLIP S. BARNETT

Phillip S. Barnett

Senior Vice President, Chief Financial Officer and Treasurer

Date: May 5, 2021

EX-32.15

Exhibit 32-15

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Delmarva Power & Light Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Delmarva Power & Light Company.

/s/    DAVID M. VELAZQUEZ

David M. Velazquez

President and Chief Executive Officer

Date: May 5, 2021

EX-32.16

Exhibit 32-16

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Delmarva Power & Light Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Delmarva Power & Light Company.

/s/    PHILLIP S. BARNETT

Phillip S. Barnett

Senior Vice President, Chief Financial Officer and Treasurer

Date: May 5, 2021

EX-32.17

Exhibit 32-17

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Atlantic City Electric Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Atlantic City Electric Company.

/s/    DAVID M. VELAZQUEZ

David M. Velazquez

President and Chief Executive Officer

Date: May 5, 2021

EX-32.18

Exhibit 32-18

Certificate Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code

The undersigned officer hereby certifies, as to the quarterly report on Form 10-Q of Atlantic City Electric Company for the quarterly period ended March 31, 2021, that (i) the report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934, and (ii) the information contained in the report fairly presents, in all material respects, the financial condition and results of operations of Atlantic City Electric Company.

/s/    PHILLIP S. BARNETT

Phillip S. Barnett

Senior Vice President, Chief Financial Officer and Treasurer

Date: May 5, 2021

XML

Cover Page	3 Months Ended
	Mar. 31, 2021 shares
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2021
Document Transition Report	false
Entity File Number	001-16169
Entity Registrant Name	EXELON CORPORATION
Entity Tax Identification Number	23-2990190
Entity Incorporation, State or Country Code	PA
Entity Address, Address Line One	10 South Dearborn Street
Entity Address, Address Line Two	P.O. Box 805379
Entity Address, City or Town	Chicago
Entity Address, State or Province	IL
Entity Address, Postal Zip Code	60680-5379
City Area Code	(800)
Local Phone Number	483-3220
Title of 12(b) Security	Common stock, without par value
Trading Symbol	EXC
Security Exchange Name	NASDAQ
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock Shares Outstanding	977,175,235
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Entity Central Index Key	0001109357
Amendment Flag	false
Exelon Generation Co L L C [Member]
Entity File Number	333-85496
Entity Registrant Name	EXELON GENERATION COMPANY, LLC
Entity Tax Identification Number	23-3064219
Entity Incorporation, State or Country Code	PA
Entity Address, Address Line One	300 Exelon Way
Entity Address, City or Town	Kennett Square
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	19348-2473
City Area Code	(610)
Local Phone Number	765-5959
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Central Index Key	0001168165
Commonwealth Edison Co [Member]
Entity File Number	001-01839
Entity Registrant Name	COMMONWEALTH EDISON COMPANY
Entity Tax Identification Number	36-0938600
Entity Incorporation, State or Country Code	IL
Entity Address, Address Line One	440 South LaSalle Street
Entity Address, City or Town	Chicago
Entity Address, State or Province	IL
Entity Address, Postal Zip Code	60605-1028
City Area Code	(312)
Local Phone Number	394-4321
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock Shares Outstanding	127,021,380
Entity Central Index Key	0000022606
PECO Energy Co [Member]
Entity File Number	000-16844
Entity Registrant Name	PECO ENERGY COMPANY
Entity Tax Identification Number	23-0970240
Entity Incorporation, State or Country Code	PA
Entity Address, Address Line One	P.O. Box 8699
Entity Address, Address Line Two	2301 Market Street
Entity Address, City or Town	Philadelphia
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	19101-8699
City Area Code	(215)
Local Phone Number	841-4000
Title of 12(b) Security	Cumulative Preferred Security, Series D
Trading Symbol	EXC/28
Security Exchange Name	NYSE
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock Shares Outstanding	170,478,507
Entity Central Index Key	0000078100
Baltimore Gas and Electric Company [Member]
Entity File Number	001-01910
Entity Registrant Name	BALTIMORE GAS AND ELECTRIC COMPANY
Entity Tax Identification Number	52-0280210
Entity Incorporation, State or Country Code	MD
Entity Address, Address Line One	2 Center Plaza
Entity Address, Address Line Two	110 West Fayette Street
Entity Address, City or Town	Baltimore
Entity Address, State or Province	MD
Entity Address, Postal Zip Code	21201-3708
City Area Code	(410)
Local Phone Number	234-5000
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock Shares Outstanding	1,000
Entity Central Index Key	0000009466
Pepco Holdings LLC [Member]
Entity File Number	001-31403
Entity Registrant Name	PEPCO HOLDINGS LLC
Entity Tax Identification Number	52-2297449
Entity Incorporation, State or Country Code	DE
Entity Address, Address Line One	701 Ninth Street, N.W.
Entity Address, City or Town	Washington, District of Columbia
Entity Address, Postal Zip Code	20068
City Area Code	(202)
Local Phone Number	872-2000
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Central Index Key	0001135971
Potomac Electric Power Company [Member]
Entity File Number	001-01072
Entity Registrant Name	POTOMAC ELECTRIC POWER COMPANY
Entity Tax Identification Number	53-0127880
Entity Address, Address Line One	701 Ninth Street, N.W.
Entity Address, City or Town	Washington, District of Columbia
Entity Address, Postal Zip Code	20068
City Area Code	(202)
Local Phone Number	872-2000
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock Shares Outstanding	100
Entity Central Index Key	0000079732
Delmarva Power and Light Company [Member]
Entity File Number	001-01405
Entity Registrant Name	DELMARVA POWER & LIGHT COMPANY
Entity Tax Identification Number	51-0084283
Entity Address, Address Line One	500 North Wakefield Drive
Entity Address, City or Town	Newark
Entity Address, State or Province	DE
Entity Address, Postal Zip Code	19702
City Area Code	(202)
Local Phone Number	872-2000
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock Shares Outstanding	1,000
Entity Central Index Key	0000027879
Atlantic City Electric Company [Member]
Entity File Number	001-03559
Entity Registrant Name	ATLANTIC CITY ELECTRIC COMPANY
Entity Tax Identification Number	21-0398280
Entity Incorporation, State or Country Code	NJ
Entity Address, Address Line One	500 North Wakefield Drive
Entity Address, City or Town	Newark
Entity Address, State or Province	DE
Entity Address, Postal Zip Code	19702
City Area Code	(202)
Local Phone Number	872-2000
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock Shares Outstanding	8,546,017
Entity Central Index Key	0000008192
DISTRICT OF COLUMBIA | Potomac Electric Power Company [Member]
Entity Incorporation, State or Country Code	DC
VIRGINIA | Potomac Electric Power Company [Member]
Entity Incorporation, State or Country Code	VA
VIRGINIA | Delmarva Power and Light Company [Member]
Entity Incorporation, State or Country Code	VA
DELAWARE | Delmarva Power and Light Company [Member]
Entity Incorporation, State or Country Code	DE

XML

Consolidated Statements of Operations and Comprehensive Income (Unaudited) - USD ($) shares in Millions, $ in Millions		3 Months Ended
		Mar. 31, 2021	Mar. 31, 2020
Operating revenues
Revenues from alternative revenue programs		$ 129	$ 67
Operating revenues from affiliates		0	1
Total operating revenues		9,890	8,747
Operating expenses
Operating and maintenance		1,979	2,204
Depreciation and amortization		1,697	1,021
Taxes other than income taxes		438	437
Total operating expenses		10,082	7,529
Gain on sales of assets and businesses		71	2
Operating income (loss)		(121)	1,220
Other income and (deductions)
Interest expense, net		(380)	(404)
Interest expense to affiliates		(6)	(6)
Other, net		225	(725)
Total other income and (deductions)		(161)	(1,135)
Income before income taxes		(282)	85
Income taxes		(19)	(294)
Equity in losses of unconsolidated affiliates		(1)	(3)
Net income (loss)		(264)	376
Net income (loss) attributable to noncontrolling interests		25	(206)
Net Income (Loss) Available to Common Stockholders, Basic		(289)	582
Other comprehensive income (loss), net of income taxes
Prior service benefit reclassified to periodic benefit cost		(1)	(10)
Actuarial loss reclassified to periodic benefit cost		56	47
Pension and non-pension postretirement benefit plan valuation adjustment		(2)	(7)
Unrealized (loss) gain on cash flow hedges		0	(1)
Unrealized gain (loss) on foreign currency translation		1	(8)
Other comprehensive income		54	21
Comprehensive income		(210)	397
Comprehensive income (loss) attributable to noncontrolling interests		25	(206)
Comprehensive income attributable to common shareholders/membership interest		$ (235)	$ 603
Average shares of common stock outstanding:
Basic average shares of common stock outstanding		977	975
Assumed exercise and/or distributions of stock-based awards		0	1
Diluted average shares of common stock outstanding	[1]	977	976
(Losses) earnings per average common share
Basic earnings per average common share		$ (0.30)	$ 0.60
Diluted earnings per average common share		$ (0.30)	$ 0.60
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount		0	0
Retained Earnings [Member]
Other income and (deductions)
Net income (loss)		$ (289)	$ 582
Exelon Generation Co L L C [Member]
Operating revenues
Operating revenues from affiliates		295	330
Total operating revenues		5,559	4,733
Operating expenses
Purchased power and/or fuel from affiliates		0	(6)
Operating and maintenance		856	1,121
Operating and maintenance from affiliates		145	142
Depreciation and amortization		940	304
Taxes other than income taxes		121	129
Total operating expenses		6,672	4,400
Gain on sales of assets and businesses		71	0
Operating income (loss)		(1,042)	333
Other income and (deductions)
Interest expense, net		(68)	(100)
Interest expense to affiliates		(4)	(9)
Other, net		167	(771)
Total other income and (deductions)		95	(880)
Income before income taxes		(947)	(547)
Income taxes		(179)	(389)
Equity in losses of unconsolidated affiliates		(1)	(3)
Net income (loss)		(769)	(161)
Net income (loss) attributable to noncontrolling interests		24	(206)
Net income attributable to membership interest		(793)	45
Other comprehensive income (loss), net of income taxes
Unrealized (loss) gain on cash flow hedges		0	(1)
Unrealized gain (loss) on foreign currency translation		1	(8)
Other comprehensive income		1	(9)
Comprehensive income		(768)	(170)
Comprehensive income (loss) attributable to noncontrolling interests		24	(206)
Comprehensive income attributable to common shareholders/membership interest		(792)	36
Commonwealth Edison Co [Member]
Operating revenues
Revenues from alternative revenue programs		54	12
Operating revenues from affiliates		6	5
Total operating revenues		1,535	1,439
Operating expenses
Purchased power and/or fuel from affiliates		85	97
Operating and maintenance		245	243
Operating and maintenance from affiliates		71	74
Depreciation and amortization		292	273
Taxes other than income taxes		75	75
Total operating expenses		1,210	1,151
Operating income (loss)		325	288
Other income and (deductions)
Interest expense, net		(93)	(91)
Interest expense to affiliates		(3)	(3)
Other, net		7	10
Total other income and (deductions)		(89)	(84)
Income before income taxes		236	204
Income taxes		39	36
Net income (loss)		197	168
Other comprehensive income (loss), net of income taxes
Comprehensive income		197	168
PECO Energy Co [Member]
Operating revenues
Revenues from alternative revenue programs		10	2
Operating revenues from affiliates		2	2
Total operating revenues		889	813
Operating expenses
Purchased power and/or fuel from affiliates		41	36
Operating and maintenance		193	179
Operating and maintenance from affiliates		41	38
Depreciation and amortization		86	86
Taxes other than income taxes		43	39
Total operating expenses		679	625
Operating income (loss)		210	188
Other income and (deductions)
Interest expense, net		(35)	(33)
Interest expense to affiliates		(3)	(3)
Other, net		5	3
Total other income and (deductions)		(33)	(33)
Income before income taxes		177	155
Income taxes		10	15
Net income (loss)		167	140
Other comprehensive income (loss), net of income taxes
Comprehensive income		167	140
PECO Energy Co [Member] | Retained Earnings [Member]
Other income and (deductions)
Net income (loss)		167	140
Baltimore Gas and Electric Company [Member]
Operating revenues
Revenues from alternative revenue programs		18	36
Operating revenues from affiliates		6	6
Total operating revenues		974	937
Operating expenses
Purchased power and/or fuel from affiliates		70	98
Operating and maintenance		152	146
Operating and maintenance from affiliates		45	42
Depreciation and amortization		152	143
Taxes other than income taxes		72	69
Total operating expenses		752	688
Operating income (loss)		222	249
Other income and (deductions)
Interest expense, net		(34)	(32)
Other, net		8	5
Total other income and (deductions)		(26)	(27)
Income before income taxes		196	222
Income taxes		(13)	41
Net income (loss)		209	181
Other comprehensive income (loss), net of income taxes
Comprehensive income		209	181
Baltimore Gas and Electric Company [Member] | Retained Earnings [Member]
Other income and (deductions)
Net income (loss)		209	181
Pepco Holdings LLC [Member]
Operating revenues
Revenues from alternative revenue programs		46	18
Operating revenues from affiliates		3	3
Total operating revenues		1,244	1,171
Operating expenses
Purchased power and/or fuel from affiliates		98	104
Operating and maintenance		216	219
Operating and maintenance from affiliates		40	38
Depreciation and amortization		210	194
Taxes other than income taxes		113	114
Total operating expenses		1,058	1,000
Gain on sales of assets and businesses		0	2
Operating income (loss)		186	173
Other income and (deductions)
Interest expense, net		(67)	(67)
Other, net		17	13
Total other income and (deductions)		(50)	(54)
Income before income taxes		136	119
Income taxes		8	11
Net income (loss)		128	108
Other comprehensive income (loss), net of income taxes
Comprehensive income attributable to common shareholders/membership interest		128	108
Potomac Electric Power Company [Member]
Operating revenues
Revenues from alternative revenue programs		26	15
Operating revenues from affiliates		1	1
Total operating revenues		553	544
Operating expenses
Purchased power and/or fuel from affiliates		74	79
Operating and maintenance		56	60
Operating and maintenance from affiliates		52	51
Depreciation and amortization		102	95
Taxes other than income taxes		90	92
Total operating expenses		466	462
Operating income (loss)		87	82
Other income and (deductions)
Interest expense, net		(34)	(34)
Other, net		12	9
Total other income and (deductions)		(22)	(25)
Income before income taxes		65	57
Income taxes		6	5
Net income (loss)		59	52
Other comprehensive income (loss), net of income taxes
Comprehensive income		59	52
Potomac Electric Power Company [Member] | Retained Earnings [Member]
Other income and (deductions)
Net income (loss)		59	52
Delmarva Power and Light Company [Member]
Operating revenues
Revenues from alternative revenue programs		9	1
Operating revenues from affiliates		2	2
Total operating revenues		382	350
Operating expenses
Purchased power and/or fuel from affiliates		20	22
Operating and maintenance		44	42
Operating and maintenance from affiliates		39	37
Depreciation and amortization		53	48
Taxes other than income taxes		17	16
Total operating expenses		309	284
Operating income (loss)		73	66
Other income and (deductions)
Interest expense, net		(15)	(16)
Other, net		3	2
Total other income and (deductions)		(12)	(14)
Income before income taxes		61	52
Income taxes		5	7
Net income (loss)		56	45
Other comprehensive income (loss), net of income taxes
Comprehensive income		56	45
Delmarva Power and Light Company [Member] | Retained Earnings [Member]
Other income and (deductions)
Net income (loss)		56	45
Atlantic City Electric Company [Member]
Operating revenues
Revenues from alternative revenue programs		11	1
Operating revenues from affiliates		1	1
Total operating revenues		310	276
Operating expenses
Purchased power and/or fuel from affiliates		4	2
Operating and maintenance		42	45
Operating and maintenance from affiliates		34	33
Depreciation and amortization		47	43
Taxes other than income taxes		2	2
Total operating expenses		282	251
Gain on sales of assets and businesses		0	2
Operating income (loss)		28	27
Other income and (deductions)
Interest expense, net		(15)	(14)
Interest expense to affiliates		0	(1)
Other, net		1	2
Total other income and (deductions)		(14)	(13)
Income before income taxes		14	14
Income taxes		0	1
Net income (loss)		14	13
Other comprehensive income (loss), net of income taxes
Comprehensive income		14	13
Atlantic City Electric Company [Member] | Retained Earnings [Member]
Other income and (deductions)
Net income (loss)		14	13
Generation commodities and services
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		5,265	4,404
Operating expenses
Purchased power and/or fuel		4,610	2,710
Generation commodities and services | Exelon Generation Co L L C [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		5,264	4,403
Operating expenses
Purchased power and/or fuel		4,610	2,710
Rate-regulated utility revenues
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		4,496	4,276
Operating expenses
Purchased power and/or fuel		1,358	1,157
Electricity, US Regulated
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		3,988	3,748
Electricity, US Regulated | Commonwealth Edison Co [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		1,475	1,422
Operating expenses
Purchased power and/or fuel		442	389
Electricity, US Regulated | PECO Energy Co [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		649	600
Operating expenses
Purchased power and/or fuel		189	164
Electricity, US Regulated | Baltimore Gas and Electric Company [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		620	595
Operating expenses
Purchased power and/or fuel		162	114
Electricity, US Regulated | Pepco Holdings LLC [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		1,124	1,086
Operating expenses
Purchased power and/or fuel		348	300
Electricity, US Regulated | Potomac Electric Power Company [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		526	528
Operating expenses
Purchased power and/or fuel		92	85
Electricity, US Regulated | Delmarva Power and Light Company [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		300	283
Operating expenses
Purchased power and/or fuel		103	88
Electricity, US Regulated | Atlantic City Electric Company [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		298	274
Operating expenses
Purchased power and/or fuel		153	126
Natural Gas, US Regulated
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		637	595
Natural Gas, US Regulated | PECO Energy Co [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		228	209
Operating expenses
Purchased power and/or fuel		86	83
Natural Gas, US Regulated | Baltimore Gas and Electric Company [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		330	300
Operating expenses
Purchased power and/or fuel		99	76
Natural Gas, US Regulated | Pepco Holdings LLC [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		71	64
Operating expenses
Purchased power and/or fuel		33	31
Natural Gas, US Regulated | Delmarva Power and Light Company [Member]
Operating revenues
Revenue from Contract with Customer, Including Assessed Tax		71	64
Operating expenses
Purchased power and/or fuel		$ 33	$ 31

[1] The number of stock options not included in the calculation of diluted common shares outstanding due to their antidilutive effect was less than 1 million for the three months ended March 31, 2021 and March 31, 2020.

XML

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Cash flows from operating activities
Net income (loss)	$ (264)	$ 376
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	2,104	1,378
Asset impairments	1	8
Gain on sales of assets and businesses	(71)	0
Deferred income taxes and amortization of investment tax credits	(142)	(245)
Net fair value changes related to derivatives	(178)	(132)
Net realized and unrealized (gains) losses on NDT funds	(118)	651
Unrealized loss on equity investments	23	0
Other non-cash operating activities	(170)	273
Changes in assets and liabilities:
Accounts receivable	(372)	800
Inventories	77	81
Accounts payable and accrued expenses	(176)	(976)
Option premiums received (paid), net	16	(38)
Collateral received (posted), net	273	(21)
Income taxes	113	(56)
Pension and non-pension postretirement benefit contributions	(537)	(531)
Other assets and liabilities	(1,840)	(488)
Net cash flows provided by operating activities	(1,261)	1,080
Cash flows from investing activities
Capital expenditures	(2,140)	(2,016)
Proceeds from NDT fund sales	2,908	1,183
Investment in NDT funds	(2,939)	(1,234)
Collection of deferred purchase price	1,574	0
Proceeds from sales of assets and businesses	680	0
Other investing activities	12	(8)
Net cash flows provided by (used in) investing activities	95	(2,075)
Cash flows from financing activities
Changes in short-term borrowings	597	109
Proceeds from short-term borrowings with maturities greater than 90 days	500	500
Issuance of long-term debt	1,705	2,652
Retirement of long-term debt	(79)	(1,032)
Dividends paid on common stock	(374)	(373)
Proceeds from employee stock plans	31	30
Other financing activities	(46)	(21)
Net cash flows provided by (used in) financing activities	2,334	1,865
Increase (Decrease) in cash, restricted cash, and cash equivalents	1,168	870
Cash, restricted cash, and cash equivalents at beginning of period	1,166	1,122
Cash, restricted cash, and cash equivalents at end of period	2,334	1,992
Supplemental Cash Flow Information
Increase (decrease) in capital expenditures not paid	(324)	(180)
Increase in deferred purchase price	1,339	0
Exelon Generation Co L L C [Member]
Cash flows from operating activities
Net income (loss)	(769)	(161)
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	1,346	661
Asset impairments	1	8
Gain on sales of assets and businesses	(71)	0
Deferred income taxes and amortization of investment tax credits	(123)	(329)
Net fair value changes related to derivatives	(178)	(127)
Net realized and unrealized (gains) losses on NDT funds	(118)	651
Unrealized loss on equity investments	23	0
Other non-cash operating activities	(202)	205
Changes in assets and liabilities:
Accounts receivable	(453)	787
Receivables from and payables to affiliates, net	59	34
Inventories	50	39
Accounts payable and accrued expenses	208	(614)
Option premiums received (paid), net	16	(38)
Collateral received (posted), net	270	(22)
Income taxes	(55)	(58)
Pension and non-pension postretirement benefit contributions	(205)	(232)
Other assets and liabilities	(1,411)	(184)
Net cash flows provided by operating activities	(1,612)	620
Cash flows from investing activities
Capital expenditures	(382)	(558)
Proceeds from NDT fund sales	2,908	1,183
Investment in NDT funds	(2,939)	(1,234)
Collection of deferred purchase price	1,574	0
Proceeds from sales of assets and businesses	680	0
Changes in Exelon/PHI intercompany money pool	0	(254)
Other investing activities	(2)	(8)
Net cash flows provided by (used in) investing activities	1,839	(871)
Cash flows from financing activities
Changes in short-term borrowings	997	275
Proceeds from short-term borrowings with maturities greater than 90 days	0	500
Issuance of long-term debt	1	1,502
Retirement of long-term debt	(35)	(1,028)
Changes in Exelon/PHI intercompany money pool	(285)	0
Distributions to member	(458)	(468)
Other financing activities	(12)	(8)
Net cash flows provided by (used in) financing activities	208	773
Increase (Decrease) in cash, restricted cash, and cash equivalents	435	522
Cash, restricted cash, and cash equivalents at beginning of period	327	449
Cash, restricted cash, and cash equivalents at end of period	762	971
Supplemental Cash Flow Information
Increase (decrease) in capital expenditures not paid	(37)	(56)
Increase in deferred purchase price	1,339	0
Commonwealth Edison Co [Member]
Cash flows from operating activities
Net income (loss)	197	168
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	292	273
Deferred income taxes and amortization of investment tax credits	63	42
Other non-cash operating activities	(9)	16
Changes in assets and liabilities:
Accounts receivable	23	9
Receivables from and payables to affiliates, net	(15)	(6)
Inventories	(1)	(2)
Accounts payable and accrued expenses	(176)	(147)
Collateral received (posted), net	5	3
Income taxes	(23)	(7)
Pension and non-pension postretirement benefit contributions	(171)	(143)
Other assets and liabilities	(159)	(132)
Net cash flows provided by operating activities	26	74
Cash flows from investing activities
Capital expenditures	(613)	(506)
Other investing activities	7	5
Net cash flows provided by (used in) investing activities	(606)	(501)
Cash flows from financing activities
Changes in short-term borrowings	(188)	(130)
Issuance of long-term debt	700	1,000
Dividends paid on common stock	(127)	(125)
Contributions from parent	198	125
Other financing activities	(9)	(13)
Net cash flows provided by (used in) financing activities	574	857
Increase (Decrease) in cash, restricted cash, and cash equivalents	(6)	430
Cash, restricted cash, and cash equivalents at beginning of period	405	403
Cash, restricted cash, and cash equivalents at end of period	399	833
Supplemental Cash Flow Information
Increase (decrease) in capital expenditures not paid	(107)	(5)
PECO Energy Co [Member]
Cash flows from operating activities
Net income (loss)	167	140
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	86	86
Deferred income taxes and amortization of investment tax credits	6	2
Other non-cash operating activities	12	22
Changes in assets and liabilities:
Accounts receivable	(5)	14
Receivables from and payables to affiliates, net	(2)	(3)
Inventories	13	15
Accounts payable and accrued expenses	(36)	(45)
Income taxes	3	14
Pension and non-pension postretirement benefit contributions	(16)	(16)
Other assets and liabilities	(103)	(84)
Net cash flows provided by operating activities	125	145
Cash flows from investing activities
Capital expenditures	(295)	(259)
Changes in Exelon/PHI intercompany money pool	(48)	(22)
Other investing activities	1	1
Net cash flows provided by (used in) investing activities	(342)	(280)
Cash flows from financing activities
Issuance of long-term debt	375	0
Changes in Exelon/PHI intercompany money pool	(40)	0
Dividends paid on common stock	(85)	(85)
Contributions from parent	0	231
Other financing activities	(4)	0
Net cash flows provided by (used in) financing activities	246	146
Increase (Decrease) in cash, restricted cash, and cash equivalents	29	11
Cash, restricted cash, and cash equivalents at beginning of period	26	27
Cash, restricted cash, and cash equivalents at end of period	55	38
Supplemental Cash Flow Information
Increase (decrease) in capital expenditures not paid	(44)	(11)
Baltimore Gas and Electric Company [Member]
Cash flows from operating activities
Net income (loss)	209	181
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	152	143
Deferred income taxes and amortization of investment tax credits	(4)	33
Other non-cash operating activities	2	(8)
Changes in assets and liabilities:
Accounts receivable	12	(28)
Receivables from and payables to affiliates, net	(15)	(13)
Inventories	9	20
Accounts payable and accrued expenses	(59)	(9)
Income taxes	(9)	7
Pension and non-pension postretirement benefit contributions	(65)	(64)
Other assets and liabilities	(103)	10
Net cash flows provided by operating activities	129	272
Cash flows from investing activities
Capital expenditures	(336)	(283)
Other investing activities	2	(6)
Net cash flows provided by (used in) investing activities	(334)	(289)
Cash flows from financing activities
Changes in short-term borrowings	156	66
Dividends paid on common stock	(74)	(62)
Net cash flows provided by (used in) financing activities	82	4
Increase (Decrease) in cash, restricted cash, and cash equivalents	(123)	(13)
Cash, restricted cash, and cash equivalents at beginning of period	145	25
Cash, restricted cash, and cash equivalents at end of period	22	12
Supplemental Cash Flow Information
Increase (decrease) in capital expenditures not paid	(80)	(35)
Pepco Holdings LLC [Member]
Cash flows from operating activities
Net income (loss)	128	108
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	210	194
Deferred income taxes and amortization of investment tax credits	4	(4)
Other non-cash operating activities	(25)	7
Changes in assets and liabilities:
Accounts receivable	56	36
Receivables from and payables to affiliates, net	(18)	(17)
Inventories	5	8
Accounts payable and accrued expenses	(24)	(16)
Income taxes	3	15
Pension and non-pension postretirement benefit contributions	(36)	(27)
Other assets and liabilities	(94)	(72)
Net cash flows provided by operating activities	209	232
Cash flows from investing activities
Capital expenditures	(456)	(376)
Other investing activities	1	1
Net cash flows provided by (used in) investing activities	(455)	(375)
Cash flows from financing activities
Changes in short-term borrowings	(368)	(100)
Issuance of long-term debt	625	150
Retirement of long-term debt	(44)	(6)
Changes in Exelon/PHI intercompany money pool	3	7
Distributions to member	(81)	(134)
Contributions from member	560	144
Other financing activities	(5)	(1)
Net cash flows provided by (used in) financing activities	690	60
Increase (Decrease) in cash, restricted cash, and cash equivalents	444	(83)
Cash, restricted cash, and cash equivalents at beginning of period	160	181
Cash, restricted cash, and cash equivalents at end of period	604	98
Supplemental Cash Flow Information
Increase (decrease) in capital expenditures not paid	(33)	(57)
Potomac Electric Power Company [Member]
Cash flows from operating activities
Net income (loss)	59	52
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	102	95
Deferred income taxes and amortization of investment tax credits	4	(2)
Other non-cash operating activities	(25)	(11)
Changes in assets and liabilities:
Accounts receivable	26	14
Receivables from and payables to affiliates, net	(9)	(11)
Inventories	1	3
Accounts payable and accrued expenses	0	6
Income taxes	2	6
Pension and non-pension postretirement benefit contributions	(5)	(4)
Other assets and liabilities	(58)	(38)
Net cash flows provided by operating activities	97	110
Cash flows from investing activities
Capital expenditures	(220)	(180)
Changes in Exelon/PHI intercompany money pool	0	(114)
Other investing activities	1	(4)
Net cash flows provided by (used in) investing activities	(219)	(298)
Cash flows from financing activities
Changes in short-term borrowings	(35)	(82)
Issuance of long-term debt	150	150
Dividends paid on common stock	(28)	(28)
Contributions from parent	138	137
Other financing activities	(1)	(1)
Net cash flows provided by (used in) financing activities	224	176
Increase (Decrease) in cash, restricted cash, and cash equivalents	102	(12)
Cash, restricted cash, and cash equivalents at beginning of period	65	63
Cash, restricted cash, and cash equivalents at end of period	167	51
Supplemental Cash Flow Information
Increase (decrease) in capital expenditures not paid	(16)	(43)
Delmarva Power and Light Company [Member]
Cash flows from operating activities
Net income (loss)	56	45
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	53	48
Deferred income taxes and amortization of investment tax credits	2	0
Other non-cash operating activities	(1)	2
Changes in assets and liabilities:
Accounts receivable	15	14
Receivables from and payables to affiliates, net	(11)	(9)
Inventories	2	3
Accounts payable and accrued expenses	11	4
Income taxes	3	7
Other assets and liabilities	(26)	(10)
Net cash flows provided by operating activities	104	104
Cash flows from investing activities
Capital expenditures	(112)	(95)
Other investing activities	0	(4)
Net cash flows provided by (used in) investing activities	(112)	(99)
Cash flows from financing activities
Changes in short-term borrowings	(146)	(2)
Issuance of long-term debt	125	0
Changes in Exelon/PHI intercompany money pool	0	37
Dividends paid on common stock	(40)	(52)
Contributions from parent	120	6
Other financing activities	(2)	0
Net cash flows provided by (used in) financing activities	57	(11)
Increase (Decrease) in cash, restricted cash, and cash equivalents	49	(6)
Cash, restricted cash, and cash equivalents at beginning of period	15	13
Cash, restricted cash, and cash equivalents at end of period	64	7
Supplemental Cash Flow Information
Increase (decrease) in capital expenditures not paid	(15)	(9)
Atlantic City Electric Company [Member]
Cash flows from operating activities
Net income (loss)	14	13
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization, and accretion, including nuclear fuel and energy contract amortization	47	43
Deferred income taxes and amortization of investment tax credits	(1)	(1)
Other non-cash operating activities	(7)	4
Changes in assets and liabilities:
Accounts receivable	13	11
Receivables from and payables to affiliates, net	1	3
Inventories	3	2
Accounts payable and accrued expenses	(11)	3
Income taxes	1	2
Pension and non-pension postretirement benefit contributions	(3)	(2)
Other assets and liabilities	(3)	(22)
Net cash flows provided by operating activities	54	56
Cash flows from investing activities
Capital expenditures	(123)	(101)
Other investing activities	0	6
Net cash flows provided by (used in) investing activities	(123)	(95)
Cash flows from financing activities
Changes in short-term borrowings	(187)	(16)
Issuance of long-term debt	350	0
Retirement of long-term debt	(44)	(5)
Changes in Exelon/PHI intercompany money pool	0	77
Dividends paid on common stock	(14)	(23)
Contributions from parent	303	1
Other financing activities	(3)	0
Net cash flows provided by (used in) financing activities	405	34
Increase (Decrease) in cash, restricted cash, and cash equivalents	336	(5)
Cash, restricted cash, and cash equivalents at beginning of period	30	28
Cash, restricted cash, and cash equivalents at end of period	366	23
Supplemental Cash Flow Information
Increase (decrease) in capital expenditures not paid	$ (2)	$ (4)

XML

Consolidated Balance Sheets (Unaudited) - USD ($) shares in Millions, $ in Millions		Mar. 31, 2021	Dec. 31, 2020
Current Assets
Cash and cash equivalents		$ 1,908	$ 663
Restricted cash and cash equivalents		374	438
Accounts receivable
Customer accounts receivable		4,017	3,597
Customer allowance for credit losses		(442)	(366)
Customer accounts receivable, net		3,575	3,231
Other accounts receivable		1,320	1,469
Other allowance for credit losses		(79)	(71)
Other accounts receivable, net		1,241	1,398
Mark-to-market derivative assets, current		568	644
Unamortized energy contract assets, current		38	38
Inventories, net
Fossil fuel and emission allowances		205	297
Materials and supplies		1,427	1,425
Regulatory assets, current		1,269	1,228
Renewable energy credits, current		694	633
Assets held for sale		11	958
Other		1,687	1,609
Total current assets		12,997	12,562
Property, plant and equipment, net		82,588	82,584
Accumulated depreciation and amortization		28,121	26,727
Deferred debits and other assets
Regulatory assets, noncurrent		8,810	8,759
Nuclear decommissioning trust funds		14,688	14,464
Investments		431	440
Goodwill		6,677	6,677
Mark-to-market derivative assets, noncurrent		491	555
Unamortized energy contract assets, noncurrent		285	294
Other		3,033	2,982
Total deferred debits and other assets		34,415	34,171
Total assets	[1]	130,000	129,317
Current Liabilities
Short-term borrowings		3,128	2,031
Long-term debt due within one year		2,281	1,819
Accounts payable		3,430	3,562
Accrued expenses		1,729	2,078
Payables to affiliates, current		5	5
Regulatory liabilities, current		663	581
Mark-to-market derivative liabilities, current		422	295
Unamortized energy contract liabilities, current		98	100
Renewable energy credit obligation		645	661
Liabilities held for sale		3	375
Other		1,176	1,264
Total current liabilities		13,580	12,771
Long-term debt		36,248	35,093
Long-term debt to financing trusts		390	390
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits		13,129	13,035
Asset retirement obligations, noncurrent		12,405	12,300
Pension obligations		3,951	4,503
Non-pension postretirement benefit obligations		1,988	2,011
Spent nuclear fuel obligation		1,208	1,208
Regulatory liabilities, noncurrent		9,130	9,485
Mark-to-market derivative liabilities, noncurrent		453	473
Unamortized energy contract liabilities, noncurrent		217	238
Other		2,988	2,942
Total deferred credits and other liabilities		45,469	46,195
Total liabilities	[1]	95,687	94,449
Commitments and contingencies
Common Stock, No Par Value		$ 0	$ 0
Shareholders' equity
Common stock, shares authorized		2,000	2,000
Common stock, shares outstanding		977	976
Common stock		$ 19,412	$ 19,373
Treasury stock, shares		2	2
Treasury stock, at cost		$ (123)	$ (123)
Retained earnings/Undistributed earnings (losses)		16,072	16,735
Accumulated other comprehensive loss, net		(3,346)	(3,400)
Total shareholders’ equity		32,015	32,585
Member’s equity
Noncontrolling interests		2,298	2,283
Total equity		34,313	34,868
Total liabilities and shareholders’ equity		130,000	129,317
Variable Interest Entity, Primary Beneficiary [Member]
Current Assets
Cash and cash equivalents		175	98
Restricted cash and cash equivalents		37	47
Accounts receivable
Customer accounts receivable, net		145	148
Unamortized energy contract assets, current		22	22
Inventories, net
Materials and supplies		242	244
Assets held for sale		0	101
Other		448	674
Total current assets		1,104	1,370
Property, plant and equipment, net		5,747	5,803
Deferred debits and other assets
Nuclear decommissioning trust funds		3,089	3,007
Unamortized energy contract assets, noncurrent		243	249
Other		47	52
Total assets		10,230	10,481
Current Liabilities
Long-term debt due within one year		90	94
Accounts payable		95	81
Accrued expenses		67	70
Unamortized energy contract liabilities, current		3	4
Liabilities held for sale		0	16
Other		1	5
Total current liabilities		256	270
Long-term debt		861	889
Deferred credits and other liabilities
Asset retirement obligations, noncurrent		2,347	2,318
Other		116	129
Total liabilities		3,580	3,606
Variable Interest Entity, Primary Beneficiary [Member] | Asset Pledged as Collateral [Member]
Deferred debits and other assets
Total assets		9,985	10,200
Variable Interest Entity, Primary Beneficiary [Member] | Nonrecourse [Member]
Deferred credits and other liabilities
Total liabilities		3,578	3,598
Exelon Generation Co L L C [Member]
Current Assets
Cash and cash equivalents		721	226
Restricted cash and cash equivalents		41	89
Accounts receivable
Customer accounts receivable		1,857	1,330
Customer allowance for credit losses		(65)	(32)
Customer accounts receivable, net		1,792	1,298
Other accounts receivable		348	352
Other accounts receivable, net		348	352
Mark-to-market derivative assets, current		569	644
Receivables from affiliates, current		106	153
Unamortized energy contract assets, current		38	38
Inventories, net
Fossil fuel and emission allowances		175	233
Materials and supplies		973	978
Renewable energy credits, current		676	621
Assets held for sale		11	958
Other		1,290	1,357
Total current assets		6,740	6,947
Property, plant and equipment, net		21,311	22,214
Accumulated depreciation and amortization		14,355	13,370
Deferred debits and other assets
Nuclear decommissioning trust funds		14,688	14,464
Investments		178	184
Goodwill		47	47
Mark-to-market derivative assets, noncurrent		491	555
Prepaid pension asset		1,736	1,558
Unamortized energy contract assets, noncurrent		285	293
Deferred income taxes		15	6
Other		1,835	1,826
Total deferred debits and other assets		19,275	18,933
Total assets	[2]	47,326	48,094
Current Liabilities
Short-term borrowings		1,837	840
Long-term debt due within one year		699	197
Accounts payable		1,529	1,253
Accrued expenses		692	788
Payables to affiliates, current		125	107
Borrowings from Exelon/PHI intercompany money pool		0	285
Mark-to-market derivative liabilities, current		392	262
Unamortized energy contract liabilities, current		5	7
Renewable energy credit obligation		645	661
Liabilities held for sale		3	375
Other		371	444
Total current liabilities		6,298	5,219
Long-term debt		5,038	5,566
Long-term debt to affiliates		323	324
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits		3,542	3,656
Asset retirement obligations, noncurrent		12,157	12,054
Non-pension postretirement benefit obligations		857	858
Spent nuclear fuel obligation		1,208	1,208
Payables to affiliates, noncurrent		2,865	3,017
Mark-to-market derivative liabilities, noncurrent		190	205
Unamortized energy contract liabilities, noncurrent		3	3
Other		1,405	1,308
Total deferred credits and other liabilities		22,227	22,309
Total liabilities	[2]	33,886	33,418
Commitments and contingencies
Shareholders' equity
Retained earnings/Undistributed earnings (losses)		1,554	2,805
Accumulated other comprehensive loss, net		(29)	(30)
Member’s equity
Membership interest		9,624	9,624
Total members' equity		11,149	12,399
Noncontrolling interests		2,291	2,277
Total equity		13,440	14,676
Total liabilities and shareholders’ equity		47,326	48,094
Exelon Generation Co L L C [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Current Assets
Cash and cash equivalents		175	98
Restricted cash and cash equivalents		33	44
Accounts receivable
Customer accounts receivable, net		145	148
Unamortized energy contract assets, current		22	22
Inventories, net
Materials and supplies		242	244
Assets held for sale		0	101
Other		443	669
Total current assets		1,095	1,362
Property, plant and equipment, net		5,747	5,803
Deferred debits and other assets
Nuclear decommissioning trust funds		3,089	3,007
Unamortized energy contract assets, noncurrent		243	249
Other		38	42
Total assets		10,212	10,463
Current Liabilities
Long-term debt due within one year		69	68
Accounts payable		95	81
Accrued expenses		67	70
Unamortized energy contract liabilities, current		3	4
Liabilities held for sale		0	16
Other		1	5
Total current liabilities		235	244
Long-term debt		861	889
Deferred credits and other liabilities
Asset retirement obligations, noncurrent		2,347	2,318
Other		116	129
Total liabilities		3,559	3,580
Exelon Generation Co L L C [Member] | Variable Interest Entity, Primary Beneficiary [Member] | Asset Pledged as Collateral [Member]
Deferred debits and other assets
Total assets		9,967	10,182
Exelon Generation Co L L C [Member] | Variable Interest Entity, Primary Beneficiary [Member] | Nonrecourse [Member]
Deferred credits and other liabilities
Total liabilities		3,557	3,572
Commonwealth Edison Co [Member]
Current Assets
Cash and cash equivalents		86	83
Restricted cash and cash equivalents		270	279
Accounts receivable
Customer accounts receivable		626	656
Customer allowance for credit losses		(103)	(97)
Customer accounts receivable, net		523	559
Other accounts receivable		243	239
Other allowance for credit losses		(22)	(21)
Other accounts receivable, net		221	218
Receivables from affiliates, current		21	22
Inventories, net
Inventories, net		170	170
Regulatory assets, current		294	279
Other		55	49
Total current assets		1,640	1,659
Property, plant and equipment, net		24,840	24,557
Accumulated depreciation and amortization		5,811	5,672
Deferred debits and other assets
Regulatory assets, noncurrent		1,840	1,749
Investments		6	6
Goodwill		2,625	2,625
Receivables from affiliates, noncurrent		2,375	2,541
Prepaid pension asset		1,165	1,022
Other		334	307
Total deferred debits and other assets		8,345	8,250
Total assets		34,825	34,466
Current Liabilities
Short-term borrowings		135	323
Long-term debt due within one year		350	350
Accounts payable		533	683
Accrued expenses		242	390
Payables to affiliates, current		80	96
Customer deposits		84	86
Regulatory liabilities, current		360	289
Mark-to-market derivative liabilities, current		31	33
Other		128	143
Total current liabilities		1,943	2,393
Long-term debt		9,324	8,633
Long-term debt to financing trusts		205	205
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits		4,427	4,341
Asset retirement obligations, noncurrent		127	126
Non-pension postretirement benefit obligations		177	173
Regulatory liabilities, noncurrent		6,172	6,403
Mark-to-market derivative liabilities, noncurrent		264	268
Other		589	595
Total deferred credits and other liabilities		11,756	11,906
Total liabilities		23,228	23,137
Commitments and contingencies
Shareholders' equity
Common stock		1,588	1,588
Other paid-in capital		8,483	8,285
Retained deficit unappropriated		(1,639)	(1,639)
Retained earnings appropriated		3,165	3,095
Total shareholders’ equity		11,597	11,329
Member’s equity
Total liabilities and shareholders’ equity		34,825	34,466
PECO Energy Co [Member]
Current Assets
Cash and cash equivalents		48	19
Restricted cash and cash equivalents		7	7
Accounts receivable
Customer accounts receivable		499	511
Customer allowance for credit losses		(130)	(116)
Customer accounts receivable, net		369	395
Other accounts receivable		140	130
Other allowance for credit losses		(11)	(8)
Other accounts receivable, net		129	122
Receivables from affiliates, current		0	2
Receivable from Exelon/PHI intercompany money pool		48	0
Inventories, net
Fossil fuel and emission allowances		15	33
Materials and supplies		43	38
Prepaid utility taxes		103	0
Regulatory assets, current		29	25
Other		22	21
Total current assets		813	662
Property, plant and equipment, net		10,352	10,181
Accumulated depreciation and amortization		3,897	3,843
Deferred debits and other assets
Regulatory assets, noncurrent		828	776
Investments		30	30
Receivables from affiliates, noncurrent		490	475
Prepaid pension asset		389	375
Other		35	32
Total deferred debits and other assets		1,772	1,688
Total assets		12,937	12,531
Current Liabilities
Long-term debt due within one year		300	300
Accounts payable		431	479
Accrued expenses		100	129
Payables to affiliates, current		46	50
Borrowings from Exelon/PHI intercompany money pool		0	40
Customer deposits		54	59
Regulatory liabilities, current		127	121
Other		31	30
Total current liabilities		1,089	1,208
Long-term debt		3,825	3,453
Long-term debt to financing trusts		184	184
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits		2,297	2,242
Asset retirement obligations, noncurrent		29	29
Non-pension postretirement benefit obligations		286	286
Regulatory liabilities, noncurrent		519	503
Other		93	93
Total deferred credits and other liabilities		3,224	3,153
Total liabilities		8,322	7,998
Commitments and contingencies
Shareholders' equity
Common stock		3,014	3,014
Retained earnings/Undistributed earnings (losses)		1,601	1,519
Total shareholders’ equity		4,615	4,533
Member’s equity
Total liabilities and shareholders’ equity		12,937	12,531
Baltimore Gas and Electric Company [Member]
Current Assets
Cash and cash equivalents		21	144
Restricted cash and cash equivalents		1	1
Accounts receivable
Customer accounts receivable		476	487
Customer allowance for credit losses		(43)	(35)
Customer accounts receivable, net		433	452
Other accounts receivable		125	117
Other allowance for credit losses		(9)	(9)
Other accounts receivable, net		116	108
Receivables from affiliates, current		0	3
Inventories, net
Fossil fuel and emission allowances		12	25
Materials and supplies		45	41
Prepaid utility taxes		43	0
Regulatory assets, current		179	168
Other		9	6
Total current assets		859	948
Property, plant and equipment, net		10,026	9,872
Accumulated depreciation and amortization		4,115	4,034
Deferred debits and other assets
Regulatory assets, noncurrent		481	481
Investments		10	10
Prepaid pension asset		314	270
Other		69	69
Total deferred debits and other assets		874	830
Total assets		11,759	11,650
Current Liabilities
Short-term borrowings		156	0
Long-term debt due within one year		300	300
Accounts payable		266	346
Accrued expenses		142	205
Payables to affiliates, current		43	61
Customer deposits		105	110
Regulatory liabilities, current		41	30
Other		83	91
Total current liabilities		1,136	1,143
Long-term debt		3,365	3,364
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits		1,609	1,521
Asset retirement obligations, noncurrent		24	23
Non-pension postretirement benefit obligations		182	189
Regulatory liabilities, noncurrent		1,016	1,109
Other		95	104
Total deferred credits and other liabilities		2,926	2,946
Total liabilities		7,427	7,453
Commitments and contingencies
Shareholders' equity
Common stock		2,318	2,318
Retained earnings/Undistributed earnings (losses)		2,014	1,879
Total shareholders’ equity		4,332	4,197
Member’s equity
Total liabilities and shareholders’ equity		11,759	11,650
Pepco Holdings LLC [Member]
Current Assets
Cash and cash equivalents		558	111
Restricted cash and cash equivalents		37	39
Accounts receivable
Customer accounts receivable		557	611
Customer allowance for credit losses		(101)	(86)
Customer accounts receivable, net		456	525
Other accounts receivable		261	260
Other allowance for credit losses		(37)	(33)
Other accounts receivable, net		224	227
Receivables from affiliates, current		0	8
Inventories, net
Fossil fuel and emission allowances		3	6
Materials and supplies		196	198
Regulatory assets, current		450	440
Other		52	45
Total current assets		1,976	1,599
Property, plant and equipment, net		15,651	15,377
Accumulated depreciation and amortization		1,930	1,811
Deferred debits and other assets
Regulatory assets, noncurrent		1,912	1,933
Investments		141	140
Goodwill		4,005	4,005
Prepaid pension asset		383	365
Deferred income taxes		9	10
Other		310	307
Total deferred debits and other assets		6,760	6,760
Total assets	[3]	24,387	23,736
Current Liabilities
Short-term borrowings		0	368
Long-term debt due within one year		304	347
Accounts payable		503	539
Accrued expenses		279	299
Payables to affiliates, current		78	104
Borrowings from Exelon/PHI intercompany money pool		24	21
Customer deposits		96	106
Regulatory liabilities, current		130	137
Unamortized energy contract liabilities, current		92	92
Other		137	141
Total current liabilities		1,643	2,154
Long-term debt		7,273	6,659
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits		2,481	2,439
Asset retirement obligations, noncurrent		59	59
Non-pension postretirement benefit obligations		80	86
Regulatory liabilities, noncurrent		1,391	1,438
Unamortized energy contract liabilities, noncurrent		214	235
Other		595	622
Total deferred credits and other liabilities		4,820	4,879
Total liabilities	[3]	13,736	13,692
Commitments and contingencies
Shareholders' equity
Retained earnings/Undistributed earnings (losses)		(21)	(68)
Member’s equity
Membership interest		10,672	10,112
Total members' equity		10,651	10,044
Total equity		10,651	10,044
Total liabilities and shareholders’ equity		24,387	23,736
Pepco Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Current Assets
Cash and cash equivalents		0	0
Restricted cash and cash equivalents		4	3
Accounts receivable
Customer accounts receivable, net		0	0
Unamortized energy contract assets, current		0	0
Inventories, net
Materials and supplies		0	0
Assets held for sale		0	0
Other		5	5
Total current assets		9	8
Property, plant and equipment, net		0	0
Deferred debits and other assets
Nuclear decommissioning trust funds		0	0
Unamortized energy contract assets, noncurrent		0	0
Other		9	10
Total assets		18	18
Current Liabilities
Long-term debt due within one year		21	26
Accounts payable		0	0
Accrued expenses		0	0
Unamortized energy contract liabilities, current		0	0
Liabilities held for sale		0	0
Other		0	0
Total current liabilities		21	26
Long-term debt		0	0
Deferred credits and other liabilities
Asset retirement obligations, noncurrent		0	0
Other		0	0
Total liabilities		21	26
Pepco Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member] | Asset Pledged as Collateral [Member]
Deferred debits and other assets
Total assets		18	18
Pepco Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member] | Nonrecourse [Member]
Deferred credits and other liabilities
Total liabilities		21	26
Potomac Electric Power Company [Member]
Current Assets
Cash and cash equivalents		134	30
Restricted cash and cash equivalents		33	35
Accounts receivable
Customer accounts receivable		252	279
Customer allowance for credit losses		(41)	(32)
Customer accounts receivable, net		211	247
Other accounts receivable		138	131
Other allowance for credit losses		(15)	(13)
Other accounts receivable, net		123	118
Receivables from affiliates, current		0	2
Inventories, net
Inventories, net		110	111
Regulatory assets, current		224	214
Other		19	13
Total current assets		854	770
Property, plant and equipment, net		7,606	7,456
Accumulated depreciation and amortization		3,746	3,697
Deferred debits and other assets
Regulatory assets, noncurrent		563	570
Investments		116	115
Prepaid pension asset		283	284
Other		71	69
Total deferred debits and other assets		1,033	1,038
Total assets		9,493	9,264
Current Liabilities
Short-term borrowings		0	35
Long-term debt due within one year		4	3
Accounts payable		213	226
Accrued expenses		165	164
Payables to affiliates, current		44	55
Customer deposits		45	51
Regulatory liabilities, current		39	46
Merger related obligation		33	33
Current portion of DC PLUG obligation		30	30
Other		30	31
Total current liabilities		603	674
Long-term debt		3,313	3,162
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits		1,209	1,189
Asset retirement obligations, noncurrent		39	39
Non-pension postretirement benefit obligations		9	13
Regulatory liabilities, noncurrent		624	644
Other		324	340
Total deferred credits and other liabilities		2,205	2,225
Total liabilities		6,121	6,061
Commitments and contingencies
Shareholders' equity
Common stock		2,196	2,058
Retained earnings/Undistributed earnings (losses)		1,176	1,145
Total shareholders’ equity		3,372	3,203
Member’s equity
Total liabilities and shareholders’ equity		9,493	9,264
Delmarva Power and Light Company [Member]
Current Assets
Cash and cash equivalents		64	15
Restricted cash and cash equivalents		0	0
Accounts receivable
Customer accounts receivable		160	176
Customer allowance for credit losses		(25)	(22)
Customer accounts receivable, net		135	154
Other accounts receivable		66	68
Other allowance for credit losses		(10)	(9)
Other accounts receivable, net		56	59
Receivables from affiliates, current		0	1
Inventories, net
Fossil fuel and emission allowances		2	6
Materials and supplies		53	51
Prepaid utility taxes		10	11
Regulatory assets, current		65	58
Renewable energy credits, current		14	10
Other		2	3
Total current assets		401	368
Property, plant and equipment, net		4,368	4,314
Accumulated depreciation and amortization		1,563	1,533
Deferred debits and other assets
Regulatory assets, noncurrent		226	222
Goodwill		8	8
Prepaid pension asset		161	162
Other		68	66
Total deferred debits and other assets		463	458
Total assets		5,232	5,140
Current Liabilities
Short-term borrowings		0	146
Long-term debt due within one year		82	82
Accounts payable		119	126
Accrued expenses		49	46
Payables to affiliates, current		24	36
Customer deposits		30	32
Regulatory liabilities, current		49	47
Other		19	20
Total current liabilities		372	535
Long-term debt		1,720	1,595
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits		734	715
Asset retirement obligations, noncurrent		14	14
Non-pension postretirement benefit obligations		14	15
Regulatory liabilities, noncurrent		474	493
Other		92	97
Total deferred credits and other liabilities		1,328	1,334
Total liabilities		3,420	3,464
Commitments and contingencies
Shareholders' equity
Common stock		1,209	1,089
Retained earnings/Undistributed earnings (losses)		603	587
Total shareholders’ equity		1,812	1,676
Member’s equity
Total liabilities and shareholders’ equity		5,232	5,140
Atlantic City Electric Company [Member]
Current Assets
Cash and cash equivalents		353	17
Restricted cash and cash equivalents		4	3
Accounts receivable
Customer accounts receivable		146	156
Customer allowance for credit losses		(35)	(32)
Customer accounts receivable, net		111	124
Other accounts receivable		69	72
Other allowance for credit losses		(12)	(11)
Other accounts receivable, net		57	61
Receivables from affiliates, current		1	6
Inventories, net
Inventories, net		34	37
Regulatory assets, current		69	75
Other		2	3
Total current assets		631	326
Property, plant and equipment, net		3,552	3,475
Accumulated depreciation and amortization		1,329	1,303
Deferred debits and other assets
Regulatory assets, noncurrent		407	395
Prepaid pension asset		39	40
Other		50	50
Total deferred debits and other assets		496	485
Total assets	[4]	4,679	4,286
Current Liabilities
Short-term borrowings		0	187
Long-term debt due within one year		218	261
Accounts payable		162	177
Accrued expenses		48	46
Payables to affiliates, current		27	31
Customer deposits		21	23
Regulatory liabilities, current		41	44
Other		9	11
Total current liabilities		526	780
Long-term debt		1,500	1,152
Deferred credits and other liabilities
Deferred income taxes and unamortized investment tax credits		629	624
Non-pension postretirement benefit obligations		16	17
Regulatory liabilities, noncurrent		266	274
Other		48	48
Total deferred credits and other liabilities		959	963
Total liabilities	[4]	2,985	2,895
Commitments and contingencies
Shareholders' equity
Common stock		1,574	1,271
Retained earnings/Undistributed earnings (losses)		120	120
Total shareholders’ equity		1,694	1,391
Member’s equity
Total liabilities and shareholders’ equity		4,679	4,286
Atlantic City Electric Company [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Current Assets
Cash and cash equivalents		0	0
Restricted cash and cash equivalents		4	3
Accounts receivable
Customer accounts receivable, net		0	0
Unamortized energy contract assets, current		0	0
Inventories, net
Materials and supplies		0	0
Assets held for sale		0	0
Other		0	0
Total current assets		4	3
Property, plant and equipment, net		0	0
Deferred debits and other assets
Nuclear decommissioning trust funds		0	0
Unamortized energy contract assets, noncurrent		0	0
Other		9	10
Total assets		13	13
Current Liabilities
Long-term debt due within one year		16	21
Accounts payable		0	0
Accrued expenses		0	0
Unamortized energy contract liabilities, current		0	0
Liabilities held for sale		0	0
Other		0	0
Total current liabilities		16	21
Long-term debt		0	0
Deferred credits and other liabilities
Asset retirement obligations, noncurrent		0	0
Other		0	0
Total liabilities		16	21
Atlantic City Electric Company [Member] | Variable Interest Entity, Primary Beneficiary [Member] | Asset Pledged as Collateral [Member]
Deferred debits and other assets
Total assets		13	13
Atlantic City Electric Company [Member] | Variable Interest Entity, Primary Beneficiary [Member] | Nonrecourse [Member]
Deferred credits and other liabilities
Total liabilities		$ 16	$ 21

[1] Exelon’s consolidated assets include $9,985 million and $10,200 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,578 million and $3,598 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 16 — Variable Interest Entities for additional information.

[2] Generation’s consolidated assets include $9,967 million and $10,182 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,557 million and $3,572 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 16 — Variable Interest Entities for additional information.

[3] PHI’s consolidated total assets include $18 million at both March 31, 2021 and December 31, 2020 of PHI's consolidated VIE that can only be used to settle the liabilities of the VIE. PHI’s consolidated total liabilities include $21 million and $26 million at March 31, 2021 and December 31, 2020, respectively, of PHI's consolidated VIE for which the VIE creditors do not have recourse to PHI. See Note 16 — Variable Interest Entities for additional information.

[4] ACE’s consolidated total assets include $13 million at both March 31, 2021 and December 31, 2020, of ACE's consolidated VIE that can only be used to settle the liabilities of the VIE. ACE’s consolidated total liabilities include $16 million and $21 million at March 31, 2021 and December 31, 2020, respectively, of ACE's consolidated VIE for which the VIE creditors do not have recourse to ACE. See Note 16 — Variable Interest Entities for additional information.

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Consolidated Statements of Changes in Shareholders Equity (Unaudited) - USD ($) shares in Thousands, $ in Millions	Total	Common Stock [Member]	Treasury Stock [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interest [Member]	Exelon Generation Co L L C [Member]	Exelon Generation Co L L C [Member] Accumulated Other Comprehensive Income (Loss) [Member]	Exelon Generation Co L L C [Member] Noncontrolling Interest [Member]	Exelon Generation Co L L C [Member] Membership Interest [Member]	Exelon Generation Co L L C [Member] Retained Earnings, Unappropriated [Member]	Commonwealth Edison Co [Member]	Commonwealth Edison Co [Member] Common Stock [Member]	Commonwealth Edison Co [Member] Retained Earnings [Member]	Commonwealth Edison Co [Member] Retained Earnings, Unappropriated [Member]	Commonwealth Edison Co [Member] Other Paid-in-Capital [Member]	Commonwealth Edison Co [Member] Retained Earnings, Appropriated	PECO Energy Co [Member]	PECO Energy Co [Member] Common Stock [Member]	PECO Energy Co [Member] Retained Earnings [Member]	Baltimore Gas and Electric Company [Member]	Baltimore Gas and Electric Company [Member] Common Stock [Member]	Baltimore Gas and Electric Company [Member] Retained Earnings [Member]	Pepco Holdings LLC [Member]	Pepco Holdings LLC [Member] Membership Interest [Member]	Pepco Holdings LLC [Member] Retained Earnings, Unappropriated [Member]	Potomac Electric Power Company [Member]	Potomac Electric Power Company [Member] Common Stock [Member]	Potomac Electric Power Company [Member] Retained Earnings [Member]	Delmarva Power and Light Company [Member]	Delmarva Power and Light Company [Member] Common Stock [Member]	Delmarva Power and Light Company [Member] Retained Earnings [Member]	Atlantic City Electric Company [Member]	Atlantic City Electric Company [Member] Common Stock [Member]	Atlantic City Electric Company [Member] Retained Earnings [Member]
Beginning balance (in shares) at Dec. 31, 2019	974,416
Beginning balance at Dec. 31, 2019	$ 34,573	$ 19,274	$ (123)	$ 16,267	$ (3,194)	$ 2,349
Beginning Balance at Dec. 31, 2019							$ 15,830	$ (32)	$ 2,346	$ 9,566	$ 3,950													$ 9,608	$ 9,618	$ (10)
Beginning Balance at Dec. 31, 2019												$ 10,677	$ 1,588		$ (1,639)	$ 7,572	$ 3,156	$ 4,178	$ 2,766	$ 1,412	$ 3,683	$ 1,907	$ 1,776				$ 2,907	$ 1,796	$ 1,111	$ 1,580	$ 977	$ 603	$ 1,276	$ 1,154	$ 122
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	$ 376			582		(206)	(161)		(206)		45	168			168			140		140	181		181	108		108	52		52	45		45	13		13
Long -Term Incentive Plan Activity (shares)	1,354
Lont-Term Incentive Plan Activity	$ (4)	(4)
Employee stock purchase plan issuances (shares)	470
Employee stock purchase plan issuances	$ 31	31
Changes in equity of noncontrolling interests	(9)					(9)	(11)		(11)
Sale of noncontrolling interests	2	2					2			2
Common stock dividends	(374)			(374)								(125)					(125)	(85)		(85)	(62)		(62)				(28)		(28)	(52)		(52)	(23)		(23)
Distributions to member							(468)				(468)													(134)		(134)
Contributions from parent												125				125		231	231					144	144		137	137		6	6		1	1
Other comprehensive income (loss), net of income taxes	$ 21				21		(9)	(9)	0		0
Ending balance (in shares) at Mar. 31, 2020	976,240
Ending balance at Mar. 31, 2020	$ 34,616	19,303	(123)	16,475	(3,173)	2,134
Ending Balance at Mar. 31, 2020							15,183	(41)	2,129	9,568	3,527													9,726	9,762	(36)
Ending Balance at Mar. 31, 2020												10,845	1,588		(1,639)	7,697	3,199	4,464	2,997	1,467	3,802	1,907	1,895				3,068	1,933	1,135	1,579	983	596	1,267	1,155	112
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends, Per Share, Declared	$ 0.38
Appropriation of retained earnings for future dividends														$ 0	(168)		168
Appropriation of retained earnings for future dividends												3,095
Beginning balance (in shares) at Dec. 31, 2020	977,466
Beginning balance at Dec. 31, 2020	$ 34,868	19,373	(123)	16,735	(3,400)	2,283
Beginning Balance at Dec. 31, 2020							14,676	(30)	2,277	9,624	2,805													10,044	10,112	(68)
Beginning Balance at Dec. 31, 2020	32,585											11,329	1,588		(1,639)	8,285	3,095	4,533	3,014	1,519	4,197	2,318	1,879				3,203	2,058	1,145	1,676	1,089	587	1,391	1,271	120
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	$ (264)			(289)		25	(769)		24		(793)	197			197			167		167	209		209	128		128	59		59	56		56	14		14
Long -Term Incentive Plan Activity (shares)	640
Lont-Term Incentive Plan Activity	$ 5	5
Employee stock purchase plan issuances (shares)	902
Employee stock purchase plan issuances	$ 34	34
Changes in equity of noncontrolling interests	(10)					(10)	(10)		(10)
Common stock dividends	(374)			(374)								(127)					(127)	(85)		(85)	(74)		(74)				(28)		(28)	(40)		(40)	(14)		(14)
Distributions to member							(458)				(458)													(81)		(81)
Contributions from parent												198				198								560	560		138	138		120	120		303	303
Other comprehensive income (loss), net of income taxes	$ 54				54		1	1	0		0
Ending balance (in shares) at Mar. 31, 2021	979,008
Ending balance at Mar. 31, 2021	$ 34,313	$ 19,412	$ (123)	$ 16,072	$ (3,346)	$ 2,298
Ending Balance at Mar. 31, 2021							$ 13,440	$ (29)	$ 2,291	$ 9,624	$ 1,554													$ 10,651	$ 10,672	$ (21)
Ending Balance at Mar. 31, 2021	$ 32,015											11,597	$ 1,588		(1,639)	$ 8,483	3,165	$ 4,615	$ 3,014	$ 1,601	$ 4,332	$ 2,318	$ 2,014				$ 3,372	$ 2,196	$ 1,176	$ 1,812	$ 1,209	$ 603	$ 1,694	$ 1,574	$ 120
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Common Stock, Dividends, Per Share, Declared	$ 0.38
Appropriation of retained earnings for future dividends												$ 3,165		$ 0	$ (197)		$ 197

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Significant Accounting Policies (All Registrants)

3 Months Ended

Mar. 31, 2021

Accounting Policies [Abstract]

Basis of Presentation and Significant Accounting Policies [Text Block]

Significant Accounting Policies (All Registrants)

Description of Business (All Registrants)

Exelon is a utility services holding company engaged in the generation, delivery and marketing of energy through Generation and the energy distribution and transmission businesses through ComEd, PECO, BGE, Pepco, DPL, and ACE.

Name of Registrant	Business	Service Territories
Exelon Generation Company, LLC	Generation, physical delivery and marketing of power across multiple geographical regions through its customer-facing business, Constellation, which sells electricity to both wholesale and retail customers. Generation also sells natural gas, renewable energy, and other energy-related products and services.	Five reportable segments: Mid-Atlantic, Midwest, New York, ERCOT, and Other Power Regions
Commonwealth Edison Company	Purchase and regulated retail sale of electricity	Northern Illinois, including the City of Chicago
	Transmission and distribution of electricity to retail customers
PECO Energy Company	Purchase and regulated retail sale of electricity and natural gas	Southeastern Pennsylvania, including the City of Philadelphia (electricity)
	Transmission and distribution of electricity and distribution of natural gas to retail customers	Pennsylvania counties surrounding the City of Philadelphia (natural gas)
Baltimore Gas and Electric Company	Purchase and regulated retail sale of electricity and natural gas	Central Maryland, including the City of Baltimore (electricity and natural gas)
	Transmission and distribution of electricity and distribution of natural gas to retail customers
Pepco Holdings LLC	Utility services holding company engaged, through its reportable segments Pepco, DPL, and ACE	Service Territories of Pepco, DPL, and ACE
Potomac Electric  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 (All Registrants)

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.

Through its business services subsidiary, BSC, Exelon provides its subsidiaries with a variety of support services at cost, including legal, human resources, financial, information technology, and supply management services. PHI also has a business services subsidiary, PHISCO, which provides a variety of support services at cost, including legal, accounting, engineering, customer operations, distribution and transmission planning, asset management, system operations, and power procurement, to PHI operating companies. The costs of BSC and PHISCO are directly charged or allocated to the applicable subsidiaries. The results of Exelon’s corporate operations are presented as “Other” within the consolidated financial statements and include intercompany eliminations unless otherwise disclosed.

The accompanying consolidated financial statements as of March 31, 2021 and for the three months ended March 31, 2021 and 2020 are unaudited but, in the opinion of the management of each Registrant include all adjustments that are considered necessary for a fair statement of the Registrants’ respective financial statements in accordance with GAAP. All adjustments are of a normal, recurring nature, except as otherwise disclosed. The

December 31, 2020 Consolidated Balance Sheets were derived from audited financial statements. 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, 2021. 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.

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Mergers, Acquisitions, and Dispositions (Exelon and Generation)

3 Months Ended

Mar. 31, 2021

Mergers, Acquisitions, and Dispositions [Abstract]

Mergers, Acquisitions, and Dispositions (Exelon and Generation)

Mergers, Acquisitions, and Dispositions (Exelon and Generation)

CENG Put Option (Exelon and Generation)

Generation owns a 50.01% membership interest in CENG, a joint venture with EDF, which wholly owns the Calvert Cliffs and Ginna nuclear stations and Nine Mile Point Unit 1, in addition to an 82% undivided ownership interest in Nine Mile Point Unit 2. CENG is 100% consolidated in Exelon's and Generation's financial statements. See Note 16 — Variable Interest Entities for additional information.

On April 1, 2014, Generation and EDF entered into various agreements including a NOSA, an amended LLC Operating Agreement, an Employee Matters Agreement, and a Put Option Agreement, among others. Under the amended LLC Operating Agreement, CENG made a $400 million special distribution to EDF and committed to make preferred distributions to Generation until Generation has received aggregate distributions of $400 million plus a return of 8.50% per annum.

Under the terms of the Put Option Agreement, EDF has the option to sell its 49.99% equity interest in CENG to Generation exercisable beginning on January 1, 2016 and thereafter until June 30, 2022. The Put Option Agreement’s terms also provide that in the event the put closing has not been completed prior to the 18-month anniversary of the exercise date, EDF may withdraw its exercise notice. In the event of a withdrawal, EDF retains the right to exercise the put option until the later of June 30, 2022 and 18 months following the date of withdrawal, but in no event later than January 1, 2024. EDF is not entitled to this withdrawal right in the event it breaches any provision of the Put Option Agreement that results in the failure of the put to close on or before the 18-month anniversary of the exercise date.

The Put Option Agreement provides that the purchase price is to be determined by agreement of the parties, or absent such agreement, by a third-party arbitration process. The third parties determining fair market value of EDF’s 49.99% interest are to take into consideration all rights and obligations under the LLC Operating Agreement and Employee Matters Agreement including but not limited to Generation’s rights with respect to any unpaid aggregate preferred distributions and the related return. As of March 31, 2021, the total unpaid aggregate preferred distributions and related return owed to Generation is $632 million. 

On November 20, 2019, Generation received notice of EDF’s intention to exercise the put option to sell its interest in CENG to Generation, and the put automatically exercised on January 19, 2020 at the end of the sixty-day advance notice period. At this time, Generation cannot reasonably predict the ultimate purchase price that will be paid to EDF for its interest in CENG. The transaction required approval by the FERC and the NYPSC, which approvals were received on July 30, 2020 and April 15, 2021, respectively. The sale process is currently expected to close in the second half of 2021.

Agreement for Sale of Generation’s Solar Business (Exelon and Generation)

On December 8, 2020, Generation entered into an agreement with an affiliate of Brookfield Renewable, for the sale of a significant portion of Generation’s solar business, including 360 MW of generation in operation or under construction across more than 600 sites across the United States. Generation will retain certain solar assets not included in this agreement, primarily Antelope Valley.

Completion of the transaction contemplated by the sale agreement was subject to the satisfaction of several closing conditions which were satisfied in the first quarter of 2021. The sale was completed on March 31, 2021 for a purchase price of $810 million. Generation received cash proceeds of $675 million, net of $125 million long-term debt assumed by the buyer and certain working capital and other post-closing adjustments. Exelon and

Generation recognized a pre-tax gain of $68 million which is included in Gain on sales of assets and businesses in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income.

See Note 17 — Debt and Credit Agreements of the Exelon 2020 Form 10-K for additional information on the SolGen nonrecourse debt included as part of the transaction.

Agreement for the Sale of a Generation Biomass Facility (Exelon and Generation)

On April 28, 2021, Generation and ReGenerate Energy Holdings, LLC (“ReGenerate”) entered into a purchase agreement, under which ReGenerate agreed to purchase Generation’s interest in the Albany Green Energy biomass facility. Completion of the transaction is expected in the second half of 2021 and is subject to various customary closing conditions.

As a result, in the second quarter of 2021, Exelon and Generation will reclassify these assets and liabilities as held for sale and expect to record an impairment loss in a range of $135 million to $150 million on a pre-tax basis, which will be recorded within Operating and maintenance expense in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income.

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Regulatory Matters (All Registrants)

3 Months Ended

Mar. 31, 2021

Regulated Operations [Abstract]

Regulatory Matters (All Registrants)

Regulatory Matters (All Registrants)

As discussed in Note 3 — Regulatory Matters of the Exelon 2020 Form 10-K, the Registrants are involved in rate and regulatory proceedings at the FERC and their state commissions. The following discusses developments in 2021 and updates to the 2020 Form 10-K.

Utility Regulatory Matters (Exelon, PHI, and the Utility Registrants)

Distribution Base Rate Case Proceedings

The following tables show the completed and pending distribution base rate case proceedings in 2021.

Completed Distribution Base Rate Case Proceedings

Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement (Decrease) Increase		Approved Revenue Requirement (Decrease) Increase		Approved ROE		Approval Date	Rate Effective Date
ComEd - Illinois(a)	April 16, 2020	Electric	$	(11)	$	(14)	8.38	%	December 9, 2020	January 1, 2021
BGE - Maryland(b)	May 15, 2020 (amended September 11, 2020)	Electric	137		81		9.50	%	December 16, 2020	January 1, 2021
		Natural Gas	91		21		9.65	%

__________

(a)ComEd's 2021 approved revenue requirement reflects an increase of $50 million for the initial year revenue requirement for 2021 and a decrease of $64 million related to the annual reconciliation for 2019. The revenue requirement for 2021 and the revenue requirement for 2019 provide for a weighted average debt and equity return on distribution rate base of 6.28%, inclusive of an allowed ROE of 8.38%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points.

(b)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 in 2021, 2022, and 2023, respectively, and natural gas revenue requirement increases of $53 million, $11 million, and $10 million in 2021, 2022, and 2023, respectively. However, the MDPSC utilized certain tax benefits to fully offset the increases in 2021 so that customer rates will remain unchanged from 2020 to 2021. The MDPSC has deferred a decision on whether to use certain tax benefits to offset the revenue requirement increases in 2022 and 2023 and BGE cannot predict the outcome.

Pending Distribution Base Rate Case Proceedings

Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement Increase		Requested ROE		Expected Approval Timing
ComEd - Illinois(a)	April 16, 2021	Electric	$	51	7.36	%	Fourth quarter of 2021
PECO - Pennsylvania	March 30, 2021	Electric	246		10.95	%	Fourth quarter of 2021
PECO - Pennsylvania	September 30, 2020	Natural Gas	69		10.95	%	Second quarter of 2021
Pepco - District of Columbia(b)	May 30, 2019 (amended June 1, 2020)	Electric	136		9.7	%	Second quarter of 2021
Pepco - Maryland(c)	October 26, 2020 (amended March 31, 2021)	Electric	104		10.2	%	Second quarter of 2021
DPL - Delaware(d)	March 6, 2020 (amended February 2, 2021)	Electric	23		10.3	%	Third quarter of 2021
ACE - New Jersey(e)	December 9, 2020 (amended February 26, 2021)	Electric	67		10.3	%	Fourth quarter of 2021

__________

(a)ComEd's 2022 requested revenue requirement reflects an increase of $40 million for the initial year revenue requirement for 2022 and an increase of $11 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 average monthly 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 average monthly yields for 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points.

(b)Pepco filed the multi-year plan enhanced proposal as an alternative to address the impacts of COVID-19. Reflects a three-year cumulative multi-year plan for 2020 through 2022 and requested revenue requirement increases of $73 million in 2022 and $63 million in 2023, to recover capital investments made during 2018 through 2020 and planned capital investments through the end of 2022.

(c)Reflects a three-year cumulative multi-year plan for April 1, 2021 through March 31, 2024 and total requested revenue requirement increases of $52 million effective April 1, 2023 and $52 million effective April 1, 2024 to recover capital investments made in 2019 and 2020 and planned capital investments through March 31, 2024.

(d)The rates went into effect on October 6, 2020, subject to refund.

(e)Requested increases are before New Jersey sales and use tax. ACE intends to put rates into effect on September 8, 2021 subject to refund.

Transmission Formula Rates

For 2021, the following total increases were included in ComEd’s electric transmission formula rate update. PECO, BGE, Pepco, DPL, and ACE intend to file by the required deadline for the annual update.

Registrant(a)	Initial Revenue Requirement Increase		Annual Reconciliation Increase		Total Revenue Requirement Increase		Allowed Return on Rate Base(b)		Allowed ROE(c)
ComEd	$	33	$	12	$	45	8.20	%	11.50	%

(a)Rates are effective June 30, 2021 - May 31, 2022, subject to review by interested parties pursuant to review protocols of ComEd's tariff.

(b)Represents the weighted average debt and equity return on transmission rate bases.

(c)As part of the FERC-approved settlements of ComEd’s 2007 rate case, the rate of return on common equity is 11.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO, and the common equity component of the ratio used to calculate the weighted average debt and equity return for the transmission formula rate is currently capped at 55%.

Regulatory Assets and Liabilities

The Utility Registrants' regulatory assets and liabilities have not changed materially since December 31, 2020, unless noted below. See Note 3 — Regulatory Matters of the Exelon 2020 Form 10-K for additional information on the specific regulatory assets and liabilities.

ComEd. Regulatory assets increased $106 million primarily due to an increase of $55 million in the Electric Distribution Formula Rate Annual Reconciliations regulatory asset, and $38 million in the Energy Efficiency Costs regulatory asset.

PECO. Regulatory assets increased $56 million primarily due to an increase of $48 million in the Deferred Income Taxes regulatory asset and $9 million in the Vacation Accrual regulatory asset.

BGE. Regulatory liabilities decreased $82 million primarily due to a decrease of $93 million in the Deferred Income Taxes regulatory liability, partially offset by an increase of $9 million in the Electric Energy and Natural Gas Costs regulatory liability.

Capitalized Ratemaking Amounts Not Recognized

The following table presents authorized amounts capitalized for ratemaking purposes related to earnings on shareholders’ investment that are not recognized for financial reporting purposes in Exelon's and the Utility Registrant's 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
March 31, 2021	$	49	$	—	$	—	$	43	$	6	$	3	$	3	$	—
December 31, 2020	51		(1)		—		45		7		4		3		—

_________

(a)Reflects ComEd's unrecognized equity returns/(losses) earned/(incurred) for ratemaking purposes on its electric distribution formula rate regulatory assets.

(b)BGE's authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholders' investment on its AMI programs.

(c)Pepco's and DPL's authorized amounts capitalized for ratemaking purposes relate to earnings on shareholders' investment on their respective AMI Programs and Energy Efficiency and Demand Response Programs. The earnings on energy efficiency are on Pepco DC and DPL DE programs only.

Generation Regulatory Matters (Exelon and Generation)

Impacts of the February 2021 Extreme Cold Weather Event and Texas-based Generating Assets Outages

Beginning on February 15, 2021, Generation’s Texas-based generating assets within the ERCOT market, specifically Colorado Bend II, Wolf Hollow II, and Handley, experienced outages as a result of extreme cold weather conditions. In addition, those weather conditions drove increased demand for service, dramatically increased wholesale power prices, and also increased gas prices in certain regions. In response to the high demand and significantly reduced total generation on the system, the PUCT directed ERCOT to use an administrative price cap of $9,000 per MWh during firm load shedding events.

The estimated impact to Exelon’s and Generation’s Net income for the first quarter of 2021 arising from these market and weather conditions was a reduction of approximately $880 million. The ultimate impact to Exelon’s and Generation’s consolidated financial statements for the full year 2021 may be affected by a number of factors, including final settlement data, the impacts of customer and counterparty credit losses, any state or federal solutions to address the financial challenges caused by the event, and related litigation and contract disputes.

During February and March 2021, various parties with differing interests, including generators and retail providers, filed requests with the PUCT to void the PUCT’s orders setting prices at $9,000 per MWh during firm load shedding events. Other requests were made for the PUCT to enforce its order and reduce prices for 32 hours between February 18 and February 19 after firm load shedding ceased and to cap ancillary services at $9,000 per MWh. Appeals of certain of the PUCT’s orders also have been filed in state court. On April 19, 2021, Generation filed a declaratory action and appeal in state court challenging the PUCT’s orders setting prices at

$9,000 per MWh. Exelon and Generation cannot predict the outcome of these proceedings or the financial statement impact.

Due to these events, a number of ERCOT market participants experienced bankruptcies, resulting in approximately a $2.9 billion payment shortfall in collections, which is allocated to the remaining ERCOT market participants. Generation recorded its portion of this obligation of approximately $28 million on a discounted basis in the first quarter of 2021, which is to be paid over a term of 96 years. Current ERCOT rules limit recovery of default from market participants to $2.5 million per month market-wide. In February 2021, the PUCT gave ERCOT discretion to disregard its current rules, but ERCOT has declined to exercise that discretion thus far. Generation's request for rehearing of this PUCT order was denied on April 17, 2021 and an appeal is pending in state court. Additionally, several pending legislative proposals were introduced in the Texas legislature during February and March 2021 concerning the amount, timing and allocation of recovery of the $2.9 billion shortfall. Exelon and Generation are monitoring the proposed legislation and cannot predict the outcome or the financial statement impact.

In addition, several other legislative proposals have been introduced in the Texas legislature during February and March 2021 addressing cold-weather preparation for power plants and natural gas production and transportation infrastructure. The proposed legislation provides the PUCT and the Railroad Commission of Texas with the option of imposing fines if the new proposed standards are not met. Exelon and Generation are monitoring the proposed legislation and cannot predict the outcome. However, such proposed legislation could have a material adverse impact in Exelon’s and Generation’s consolidated financial statements.

In February 2021, more than 70 local distribution companies (LDCs) in multiple states throughout the mid-continent region, where Generation serves natural gas transportation customers, issued operational flow orders (OFOs), curtailments or other limitations on natural gas use to preserve adequate pressure on the system. When in effect, gas use above these limitations is severely penalized according to the LDCs’ tariff. Gas supply in many states became restricted due to wells freezing and pipeline compression disruption, while demand was increasing due to the extreme cold temperatures, resulting in extremely high natural gas prices. Due to the extraordinary circumstances, many LDCs and natural gas pipelines are either voluntarily waiving or seeking regulatory approvals to waive the penalties associated with these restrictions. During March 2021, three natural gas pipelines filed individual petitions with the FERC requesting approval to waive these penalties. Generation also filed motions in March 2021 to intervene with the FERC in support of these requests from the pipelines. On March 25, 2021, the FERC issued an order on one of the petitions approving the request to waive the penalties for February 15, 2021. On April 23, 2021, Generation and several other entities filed a request for rehearing and a complaint to expand the order to include additional days of the weather events in February, from February 15 through February 19, 2021. On April 9, 2021 and April 19, 2021, the FERC issued orders on the remaining petitions approving the requests to waive the penalties. Exelon and Generation cannot predict the outcome of the FERC proceeding or the determinations made by the LDCs.

New Jersey Regulatory Matters

New Jersey Clean Energy Legislation. On May 23, 2018, New Jersey enacted legislation that established a ZEC program that provides compensation for nuclear plants that demonstrate to the NJBPU that they meet certain requirements, including that they make a significant contribution to air quality in the state and that their revenues are insufficient to cover their costs and risks. Under the legislation, the NJBPU will issue ZECs to qualifying nuclear power plants and the electric distribution utilities in New Jersey, including ACE, will be required to purchase those ZECs. On April 18, 2019, the NJBPU approved the award of ZECs to Salem 1 and Salem 2. Upon approval, Generation began recognizing revenue for the sale of New Jersey ZECs in the month they are generated. On March 19, 2021, a three-judge panel of the Superior Court of New Jersey Appellate Division unanimously affirmed the NJBPU’s April 2019 order awarding ZECs for the first eligibility period. On April 8, 2021, New Jersey Rate Counsel filed a notice of appeal of the Superior Court’s order to the New Jersey Supreme Court. Exelon and Generation cannot predict the outcome of the appeal. On October 1, 2020, PSEG and Generation filed applications seeking ZECs for the second eligibility period (June 2022 through May 2025). On April 27, 2021, the NJBPU approved the award of ZECs to Salem 1 and Salem 2 for the second eligibility period. See Note 7 — Early Plant Retirements for additional information related to Salem.

New England Regulatory Matters

Mystic Units 8 & 9 and Everett Marine Terminal Cost of Service Agreement (Exelon and Generation). On March 29, 2018, Generation notified grid operator ISO-NE of its plans to early retire Mystic Units 8 and 9 absent regulatory reforms on June 1, 2022. On May 16, 2018, Generation made a filing with FERC to establish cost-of-service compensation and terms and conditions of service for Mystic Units 8 & 9 for the period between June 1, 2022 - May 31, 2024. On December 20, 2018, FERC issued an order accepting the cost of service compensation, reflecting a number of adjustments to the annual fixed revenue requirement and allowing for recovery of a substantial portion of the costs associated with the adjacent Everett Marine Terminal acquired by Generation in October 2018. Those adjustments were reflected in a compliance filing made on March 1, 2019. In the December 20, 2018 order, FERC also directed a paper hearing on ROE using a new methodology. On January 22, 2019, Exelon and several other parties filed requests for rehearing of certain findings in the order.

On July 17, 2020, FERC issued three orders, which together affirmed the recovery of key elements of Mystic's cost of service compensation, including recovery of costs associated with the operation of the Everett Marine Terminal. FERC directed a downward adjustment to the rate base for Mystic Units 8 and 9, the effect of which will be partially offset by elimination of a crediting mechanism for third party gas sales during the term of the cost of service agreement. In addition, several parties filed protests to a compliance filing by Generation on September 15, 2020, taking issue with how gross plant in-service was calculated, and Generation filed an answer to the protests on October 21, 2020. On December 21, 2020, FERC issued an order on rehearing of the three July 17, 2020 orders, clarifying several cost of service provisions. Several parties appealed the December 21, 2020 order to the U.S. Court of Appeals for the D.C. Circuit and that appeal was consolidated with appeals of orders issued December 20, 2018 and July 17, 2020 in the Mystic proceeding. The briefing schedule for the consolidated appeal has not yet been set.

On February 25, 2021, Mystic made its filing to comply with the December 21, 2020 order. On April 26, 2021, FERC rejected Mystic’s language and directed another compliance filing relating to the claw back provision language, which only applies if Mystic 8 and 9 were to continue operation after the conclusion of the cost-of-service period. FERC’s April 26, 2021 order also accepted in part and rejected in part Mystic’s September 15, 2020 compliance filing. It directed a further compliance filing in 60 days consistent with the information provided in Mystic’s October 21, 2020 answer to protests.

On August 25, 2020, a group of New England generators filed a complaint against Generation seeking to extend the scope of the claw back provision in the cost-of-service agreement, whereby Generation would refund certain amounts recovered during the term of the cost of service if it returns to market afterwards. On April 15, 2021 FERC dismissed the complaint.

On February 16, 2021, Generation filed an unopposed motion to voluntarily dismiss an appeal filed with the U.S. Court of Appeals for the D.C. Circuit stemming from a June 2020 complaint filed with the FERC against ISO-NE over failures to follow its tariff in evaluating Mystic for transmission security for the 2024 to 2025 Capacity Commitment Period, which was granted on February 18, 2021.

See Note 7 — Early Plant Retirements for additional information on the impacts of Generation’s August 2020 decision to retire Mystic Units 8 & 9 upon expiration of the cost of service agreement.

Federal Regulatory Matters

Operating License Renewals

Conowingo Hydroelectric Project. On August 29, 2012, Generation submitted a hydroelectric license application to FERC for a new license for the Conowingo Hydroelectric Project (Conowingo). In connection with Generation’s efforts to obtain a water quality certification pursuant to Section 401 of the Clean Water Act (401 Certification) from MDE for Conowingo, Generation had been working with MDE and other stakeholders to resolve water quality licensing issues, including: (1) water quality, (2) fish habitat, and (3) sediment.

On April 27, 2018, MDE issued its 401 Certification for Conowingo. On October 29, 2019, Generation and MDE filed with FERC a Joint Offer of Settlement (Offer of Settlement) that would resolve all outstanding issues relating to the 401 Certification. Pursuant to the Offer of Settlement, the parties submitted Proposed License Articles to FERC to be incorporated by FERC into the new license in accordance with FERC’s discretionary authority under the Federal Power Act.

On March 19, 2021, FERC issued a new 50-year license for Conowingo, effective March 1, 2021. FERC adopted the Proposed License Articles into the new license only making modifications it deemed necessary to allow FERC to enforce the Proposed License Articles. Consistent with the Offer of Settlement, FERC found that MDE waived its 401 Certification.

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Revenue from Contracts with Customers (All Registrants)

3 Months Ended

Mar. 31, 2021

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers [Text Block]

Revenue from Contracts with Customers (All Registrants)

The Registrants recognize revenue from contracts with customers to depict the transfer of goods or services to customers at an amount that the entities expect to be entitled to in exchange for those goods or services. Generation’s primary sources of revenue include competitive sales of power, natural gas, and other energy-related products and services. The Utility Registrants’ primary sources of revenue include regulated electric and gas tariff sales, distribution, and transmission services.

See Note 4 — Revenue from Contracts with Customers of the Exelon 2020 Form 10-K for additional information regarding the primary sources of revenue for the Registrants.

Contract Balances (All Registrants)

Contract Assets

Generation records contract assets for the revenue recognized on the construction and installation of energy efficiency assets and new power generating facilities before Generation has an unconditional right to bill for and receive the consideration from the customer. These contract assets are subsequently reclassified to receivables when the right to payment becomes unconditional. Generation records contract assets and contract receivables within Other current assets and Customer accounts receivable, net, respectively, within Exelon’s and Generation’s Consolidated Balance Sheets.

The following table provides a rollforward of the contract assets reflected in Exelon's and Generation's Consolidated Balance Sheets for the three months ended March 31, 2021 and 2020. The Utility Registrants do not have any contract assets.

	Exelon		Generation
Balance as of December 31, 2020	$	144	$	144
Amounts reclassified to receivables	(16)		(16)
Revenues recognized	13		13
Amounts previously held-for-sale	12		12
Balance as of March 31, 2021	$	153	$	153
	Exelon		Generation
Balance as of December 31, 2019	$	174	$	174
Amounts reclassified to receivables	(19)		(19)
Revenues recognized	17		17
Balance as of March 31, 2020	$	172	$	172

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 within Other current liabilities and Other noncurrent liabilities within the Registrants' Consolidated Balance Sheets.

For Generation, these contract liabilities primarily relate to upfront consideration received or due for equipment service plans, and the Illinois ZEC program that introduces a cap on the total consideration to be received by Generation.

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, Generation's, PHI's, Pepco's, DPL's, and ACE's Consolidated Balance Sheets for the three months ended March 31, 2021 and 2020. As of March 31, 2021 and December 31, 2020, ComEd's, PECO's, and BGE's contract liabilities were immaterial.

	Exelon		Generation		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	151	$	84	$	118	$	94	$	12	$	12
Consideration received or due	20		31		—		—		—		—
Revenues recognized	(27)		(64)		(2)		(2)		—		—
Amounts previously held-for-sale	3		3		—		—		—		—
Balance as of March 31, 2021	$	147	$	54	$	116	$	92	$	12	$	12
	Exelon		Generation		PHI		Pepco		DPL		ACE
Balance as of December 31, 2019	$	33	$	71	$	—	$	—	$	—	$	—
Consideration received or due	20		55		—		—		—		—
Revenues recognized	(24)		(70)		—		—		—		—
Balance as of March 31, 2020	$	29	$	56	$	—	$	—	$	—	$	—

The following table reflects revenues recognized in the three months ended March 31, 2021 and 2020, which were included in contract liabilities at December 31, 2020 and 2019, respectively:

	Three Months Ended March 31,
	2021		2020
Exelon	$	17	$	9
Generation	39		19
PHI	2		—
Pepco	2		—

Transaction Price Allocated to Remaining Performance Obligations (All Registrants)

The following table shows the amounts of future revenues expected to be recorded in each year for performance obligations that are unsatisfied or partially unsatisfied as of March 31, 2021. 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 Generation's power and gas sales contracts as they contain variable volumes and/or variable pricing. This disclosure also 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.

	2021		2022		2023		2024		2025 and thereafter		Total
Exelon	$	233	$	100	$	56	$	41	$	330	$	760
Generation	286		131		56		35		243		751
PHI	7		8		8		6		87		116
Pepco	5		6		6		5		70		92
DPL	1		1		1		—		9		12
ACE	1		1		1		1		8		12

Revenue Disaggregation (All Registrants)

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

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Segment Information (All Registrants)

3 Months Ended

Mar. 31, 2021

Segment Reporting [Abstract]

Segment Information (All Registrants)

Segment Information (All Registrants)

Operating segments for each of the Registrants are determined based on information used by the CODM in deciding how to evaluate performance and allocate resources at each of the Registrants.

Exelon has eleven reportable segments, which include Generation's five reportable segments consisting of the Mid-Atlantic, Midwest, New York, ERCOT, and all other power regions referred to collectively as “Other Power Regions” and ComEd, PECO, BGE, and PHI's three reportable segments consisting of Pepco, DPL, and ACE. ComEd, PECO, BGE, Pepco, DPL, and ACE each represent a single reportable segment, and as such, no separate segment information is provided for these Registrants. Exelon, ComEd, PECO, BGE, Pepco, DPL, and ACE's CODMs evaluate the performance of and allocate resources to ComEd, PECO, BGE, Pepco, DPL, and ACE based on net income.

The basis for Generation's reportable segments is the integrated management of its electricity business that is located in different geographic regions, and largely representative of the footprints of ISO/RTO and/or NERC regions, which utilize multiple supply sources to provide electricity through various distribution channels (wholesale and retail). Generation's hedging strategies and risk metrics are also aligned to these same geographic regions. Descriptions of each of Generation’s five reportable segments are as follows:

•Mid-Atlantic represents operations in the eastern half of PJM, which includes New Jersey, Maryland, Virginia, West Virginia, Delaware, the District of Columbia, and parts of Pennsylvania and North Carolina.

•Midwest represents operations in the western half of PJM and the United States footprint of MISO, excluding MISO’s Southern Region.

•New York represents operations within NYISO.

•ERCOT represents operations within Electric Reliability Council of Texas.

•Other Power Regions:

•New England represents the operations within ISO-NE.

•South represents operations in the FRCC, MISO’s Southern Region, and the remaining portions of the SERC not included within MISO or PJM.

•West represents operations in the WECC, which includes California ISO.

•Canada represents operations across the entire country of Canada and includes AESO, OIESO, and the Canadian portion of MISO.

The CODMs for Exelon and Generation evaluate the performance of Generation’s electric business activities and allocate resources based on RNF. Generation believes that RNF is a useful measurement of operational performance. RNF is not a presentation defined under GAAP and may not be comparable to other companies’ presentations or deemed more useful than the GAAP information provided elsewhere in this report. Generation’s operating revenues include all sales to third parties and affiliated sales to the Utility Registrants. Purchased power costs include all costs associated with the procurement and supply of electricity including capacity, energy, and ancillary services. Fuel expense includes the fuel costs for Generation’s owned generation and fuel costs associated with tolling agreements. The results of Generation's other business activities are not regularly reviewed by the CODM and are therefore not classified as operating segments or included in the regional reportable segment amounts. These activities include natural gas, as well as other miscellaneous business activities that are not significant to Generation's overall operating revenues or results of operations. Further,

Generation’s unrealized mark-to-market gains and losses on economic hedging activities and its amortization of certain intangible assets and liabilities relating to commodity contracts recorded at fair value from mergers and acquisitions are also excluded from the regional reportable segment amounts. Exelon and Generation do not use a measure of total assets in making decisions regarding allocating resources to or assessing the performance of these reportable segments.

An analysis and reconciliation of the Registrants’ reportable segment information to the respective information in the consolidated financial statements for the three months ended March 31, 2021 and 2020 is as follows:

Three Months Ended March 31, 2021 and 2020

	Generation		ComEd		PECO		BGE		PHI		Other(a)		Intersegment Eliminations		Exelon
Operating revenues(b):
2021
Competitive businesses electric revenues	$	4,187	$	—	$	—	$	—	$	—	$	—	$	(293)	$	3,894
Competitive businesses natural gas revenues	1,326		—		—		—		—		—				1,326
Competitive businesses other revenues	46		—		—		—		—		—		(1)		45
Rate-regulated electric revenues	—		1,535		661		632		1,170		—		(10)		3,988
Rate-regulated natural gas revenues	—		—		228		342		71		—		(4)		637
Shared service and other revenues	—		—		—		—		3		491		(494)		—
Total operating revenues	$	5,559	$	1,535	$	889	$	974	$	1,244	$	491	$	(802)	$	9,890
2020
Competitive businesses electric revenues	$	3,752	$	—	$	—	$	—	$	—	$	—	$	(326)	$	3,426
Competitive businesses natural gas revenues	672		—		—		—		—		—		(3)		669
Competitive businesses other revenues	309		—		—		—		—		—		(1)		308
Rate-regulated electric revenues	—		1,439		604		613		1,104		—		(12)		3,748
Rate-regulated natural gas revenues	—		—		209		324		64		—		(2)		595
Shared service and other revenues	—		—		—		—		3		480		(482)		1
Total operating revenues	$	4,733	$	1,439	$	813	$	937	$	1,171	$	480	$	(826)	$	8,747
Intersegment revenues(c):
2021	$	295	$	6	$	2	$	6	$	3	$	487	$	(799)	$	—
2020	330		5		2		6		3		479		(824)		1
Depreciation and amortization:

	Generation		ComEd		PECO		BGE		PHI		Other(a)		Intersegment Eliminations		Exelon
2021	$	940	$	292	$	86	$	152	$	210	$	17	$	—	$	1,697
2020	304		273		86		143		194		21		—		1,021
Operating expenses:
2021	$	6,672	$	1,210	$	679	$	752	$	1,058	$	492	$	(781)	$	10,082
2020	4,400		1,151		625		688		1,000		481		(816)		7,529
Interest expense, net:
2021	$	72	$	96	$	38	$	34	$	67	$	79	$	—	$	386
2020	109		94		36		32		67		72		—		410
Income (loss) before income taxes:
2021	$	(947)	$	236	$	177	$	196	$	136	$	(80)	$	—	$	(282)
2020	(547)		204		155		222		119		(69)		1		85
Income Taxes:
2021	$	(179)	$	39	$	10	$	(13)	$	8	$	116	$	—	$	(19)
2020	(389)		36		15		41		11		(8)		—		(294)
Net income (loss):
2021	$	(769)	$	197	$	167	$	209	$	128	$	(196)	$	—	$	(264)
2020	(161)		168		140		181		108		(61)		1		376
Capital Expenditures:
2021	$	382	$	613	$	295	$	336	$	456	$	58	$	—	$	2,140
2020	558		506		259		283		376		34		—		2,016
Total assets:
March 31, 2021	$	47,326	$	34,825	$	12,937	$	11,759	$	24,387	$	8,788	$	(10,022)	$	130,000
December 31, 2020	48,094		34,466		12,531		11,650		23,736		9,005		(10,165)		129,317

__________

(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 17 — Supplemental Financial Information for additional information on total utility taxes.

(c)Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory accounting guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. See Note 18 — Related Party Transactions for additional information on intersegment revenues.

PHI:

	Pepco		DPL		ACE		Other(a)		Intersegment Eliminations		PHI
Operating revenues(b):
2021
Rate-regulated electric revenues	$	553	$	311	$	310	$	—	$	(4)	$	1,170
Rate-regulated natural gas revenues	—		71		—		—		—		71
Shared service and other revenues	—		—		—		95		(92)		3
Total operating revenues	$	553	$	382	$	310	$	95	$	(96)	$	1,244
2020
Rate-regulated electric revenues	$	544	$	286	$	276	$	—	$	(2)	$	1,104
Rate-regulated natural gas revenues	—		64		—		—		—		64
Shared service and other revenues	—		—		—		93		(90)		3
Total operating revenues	$	544	$	350	$	276	$	93	$	(92)	$	1,171
Intersegment revenues(c):
2021	$	1	$	2	$	1	$	95	$	(96)	$	3
2020	1		2		1		92		(93)		3
Depreciation and amortization:
2021	$	102	$	53	$	47	$	8	$	—	$	210
2020	95		48		43		9		(1)		194
Operating expenses:
2021	$	466	$	309	$	282	$	97	$	(96)	$	1,058
2020	462		284		251		93		(90)		1,000
Interest expense, net:
2021	$	34	$	15	$	15	$	3	$	—	$	67
2020	34		16		15		3		(1)		67
Income (loss) before income taxes:
2021	$	65	$	61	$	14	$	(4)	$	—	$	136
2020(d)	57		52		14		(4)		—		119
Income Taxes:
2021	$	6	$	5	$	—	$	(3)	$	—	$	8
2020	5		7		1		(2)		—		11
Net income (loss):
2021	$	59	$	56	$	14	$	(1)	$	—	$	128
2020	52		45		13		(2)		—		108
Capital Expenditures:
2021	$	220	$	112	$	123	$	1	$	—	$	456
2020	180		95		101		—		—		376
Total assets:
March 31, 2021	$	9,493	$	5,232	$	4,679	$	5,020	$	(37)	$	24,387
December 31, 2020	9,264		5,140		4,286		5,079		(33)		23,736

__________

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

(b)Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 17 — Supplemental Financial Information for additional information on total utility taxes.

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

(d)The Income (loss) before income taxes in Other and Intersegment Eliminations have been adjusted by an offsetting $110 million in 2020.

The following tables disaggregate the Registrants' revenue recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. For Generation, the disaggregation of revenues reflects Generation’s two primary products of

power sales and natural gas sales, with further disaggregation of power sales provided by geographic region. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of rate-regulated electric sales and rate-regulated natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon’s disaggregated revenues are consistent with Generation and the Utility Registrants, but exclude any intercompany revenues.

Competitive Business Revenues (Generation):

	Three Months Ended March 31, 2021
	Revenues from external customers(a)						Intersegment Revenues		Total Revenues
	Contracts with customers		Other(b)		Total
Mid-Atlantic	$	1,174	$	(14)	$	1,160	$	5	$	1,165
Midwest	1,009		(11)		998		—		998
New York	382		(45)		337		—		337
ERCOT	353		(101)		252		5		257
Other Power Regions	1,172		268		1,440		(10)		1,430
Total Competitive Businesses Electric Revenues	4,090		97		4,187		—		4,187
Competitive Businesses Natural Gas Revenues	864		462		1,326		—		1,326
Competitive Businesses Other Revenues(c)	89		(43)		46		—		46
Total Generation Consolidated Operating Revenues	$	5,043	$	516	$	5,559	$	—	$	5,559

	Three Months Ended March 31, 2020
	Revenues from external customers(a)						Intersegment revenues		Total Revenues
	Contracts with customers		Other(b)		Total
Mid-Atlantic	$	1,264	$	(96)	$	1,168	$	6	$	1,174
Midwest	944		64		1,008		(6)		1,002
New York	335		(21)		314		—		314
ERCOT	155		28		183		7		190
Other Power Regions	1,007		72		1,079		(7)		1,072
Total Competitive Businesses Electric Revenues	3,705		47		3,752		—		3,752
Competitive Businesses Natural Gas Revenues	503		169		672		—		672
Competitive Businesses Other Revenues(c)	99		210		309		—		309
Total Generation Consolidated Operating Revenues	$	4,307	$	426	$	4,733	$	—	$	4,733

__________

(a)Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants.

(b)Includes revenues from derivatives and leases.

(c)Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market losses of $84 million and gains of $179 million in 2021 and 2020, respectively, and elimination of intersegment revenues.

Revenues net of purchased power and fuel expense (Generation):

	Three Months Ended March 31, 2021						Three Months Ended March 31, 2020
	RNF from external customers(a)		Intersegment RNF		Total RNF		RNF from external customers(a)		Intersegment RNF		Total RNF
Mid-Atlantic	$	562	$	5	$	567	$	559	$	8	$	567
Midwest	702		—		702		732		(5)		727
New York	240		2		242		189		4		193
ERCOT	(1,036)		(148)		(1,184)		76		4		80
Other Power Regions	250		(33)		217		177		(19)		158
Total Revenues net of purchased power and fuel expense for Reportable Segments	718		(174)		544		1,733		(8)		1,725
Other(b)	231		174		405		296		8		304
Total Generation Revenues net of purchased power and fuel expense	$	949	$	—	$	949	$	2,029	$	—	$	2,029

__________

(a)Includes purchases and sales from/to third parties and affiliated sales to the Utility Registrants.

(b)Other represents activities not allocated to a region. See text above for a description of included activities. Primarily includes:

•unrealized mark-to-market gains of $175 million and gains of $132 million in 2021 and 2020, respectively;

•accelerated nuclear fuel amortization associated with announced early plant retirements as discussed in Note 7 - Early Plant Retirements of $54 million in 2021; and

• the elimination of intersegment RNF.

Electric and Gas Revenue by Customer Class (Utility Registrants):

	Three Months Ended March 31, 2021
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Rate-regulated electric revenues
Residential	$	741	$	433	$	362	$	605	$	253	$	190	$	162
Small commercial & industrial	367		100		69		118		33		46		39
Large commercial & industrial	134		57		105		248		184		21		43
Public authorities & electric railroads	11		9		7		13		6		4		3
Other(a)	220		52		77		143		51		41		52
Total rate-regulated electric revenues(b)	$	1,473	$	651	$	620	$	1,127	$	527	$	302	$	299
Rate-regulated natural gas revenues
Residential	$	—	$	160	$	216	$	46	$	—	$	46	$	—
Small commercial & industrial	—		59		35		18		—		18		—
Large commercial & industrial	—		—		54		2		—		2		—
Transportation	—		7		—		4		—		4		—
Other(c)	—		2		31		1		—		1		—
Total rate-regulated natural gas revenues(d)	$	—	$	228	$	336	$	71	$	—	$	71	$	—
Total rate-regulated revenues from contracts with customers	$	1,473	$	879	$	956	$	1,198	$	527	$	373	$	299
Other revenues
Revenues from alternative revenue programs	$	54	$	10	$	18	$	46	$	26	$	9	$	11
Other rate-regulated electric revenues(e)	8		—		—		—		—		—		—
Other rate-regulated natural gas revenues(e)	—		—		—		—		—		—		—
Total other revenues	$	62	$	10	$	18	$	46	$	26	$	9	$	11
Total rate-regulated revenues for reportable segments	$	1,535	$	889	$	974	$	1,244	$	553	$	382	$	310

	Three Months Ended March 31, 2020
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Rate-regulated electric revenues
Residential	$	701	$	382	$	339	$	534	$	236	$	161	$	137
Small commercial & industrial	362		99		67		115		35		43		37
Large commercial & industrial	134		53		103		253		188		23		42
Public authorities & electric railroads	13		7		7		15		9		3		3
Other(a)	211		58		79		169		60		54		55
Total rate-regulated electric revenues(b)	$	1,421	$	599	$	595	$	1,086	$	528	$	284	$	274
Rate-regulated natural gas revenues
Residential	$	—	$	150	$	206	$	40	$	—	$	40	$	—
Small commercial & industrial	—		51		34		17		—		17		—
Large commercial & industrial	—		—		51		1		—		1		—
Transportation	—		6		—		4		—		4		—
Other(c)	—		1		9		2		—		2		—
Total rate-regulated natural gas revenues(d)	$	—	$	208	$	300	$	64	$	—	$	64	$	—
Total rate-regulated revenues from contracts with customers	$	1,421	$	807	$	895	$	1,150	$	528	$	348	$	274
Other revenues
Revenues from alternative revenue programs	$	12	$	2	$	36	$	18	$	15	$	1	$	1
Other rate-regulated electric revenues(e)	6		3		3		3		1		1		1
Other rate-regulated natural gas revenues(e)	—		1		3		—		—		—		—
Total other revenues	$	18	$	6	$	42	$	21	$	16	$	2	$	2
Total rate-regulated revenues for reportable segments	$	1,439	$	813	$	937	$	1,171	$	544	$	350	$	276

__________

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

(b)Includes operating revenues from affiliates in 2021 and 2020 respectively of:

•$6 million, $5 million at ComEd

•$1 million, $2 million at PECO

•$2 million, $6 million at BGE

•$3 million, $3 million at PHI

•$1 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 2021 and 2020 respectively of:

•less than $1 million at PECO for both 2021 and 2020

•$4 million, $3 million at BGE

(e)Includes late payment charge revenues.

XML

Accounts Receivable (All Registrants)

3 Months Ended

Mar. 31, 2021

Credit Loss [Abstract]

Accounts Receivable (All Registrants) [Text Block]

Accounts Receivable (All Registrants)

Allowance for Credit Losses on Accounts Receivable (All Registrants)

The following tables present the rollforward of Allowance for Credit Losses on Customer Accounts Receivable.

	Three Months Ended March 31, 2021
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	366	$	32	$	97	$	116	$	35	$	86	$	32	$	22	$	32
Plus: Current period provision for expected credit losses(a)	104		34		21		20		9		20		11		6		3
Less: Write-offs, net of recoveries(b)	28		1		15		6		1		5		2		3		—
Balance as of March 31, 2021	$	442	$	65	$	103	$	130	$	43	$	101	$	41	$	25	$	35
	Three Months Ended March 31, 2020
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2019	$	243	$	80	$	59	$	55	$	12	$	37	$	13	$	11	$	13
Plus: Current period provision for expected credit losses	55		4		18		18		8		7		3		2		2
Less: Write-offs, net of recoveries(b)	20		3		6		7		2		2		1		—		1
Balance as of March 31, 2020	$	278	$	81	$	71	$	66	$	18	$	42	$	15	$	13	$	14

_________

(a)For Generation, primarily relates to the impacts of the February 2021 extreme cold weather event. See Note 3 — Regulatory Matters for additional information. For the Utility Registrants, the increase is primarily as a result of increased receivable balances due to the colder weather and the increased aging of receivables, the temporary suspension of customer disconnections for non-payment, temporary cessation of new late payment fees, and reconnection of service to customers previously disconnected due to COVID-19.

(b)Recoveries were not material to the Registrants.

The following tables present the rollforward of Allowance for Credit Losses on Other Accounts Receivable.

	Three Months Ended March 31, 2021
	Exelon		Generation		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 for expected credit losses	10		—		1		4		1		4		2		1		1
Less: Write-offs, net of recoveries(a)	2		—		—		1		1		—		—		—		—
Balance as of March 31, 2021	$	79	$	—	$	22	$	11	$	9	$	37	$	15	$	10	$	12
	Three Months Ended March 31, 2020
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2019	$	48	$	—	$	20	$	7	$	5	$	16	$	7	$	4	$	5
Plus: Current period provision for expected credit losses	8		—		3		1		2		2		1		—		1
Less: Write-offs, net of recoveries(a)	4		—		1		1		2		—		—		—		—
Balance as of March 31, 2020	$	52	$	—	$	22	$	7	$	5	$	18	$	8	$	4	$	6

_________

(a)Recoveries were not material to the Registrants.

Unbilled Customer Revenue (All Registrants)

The following table provides additional information about unbilled customer revenues recorded in the Registrants' Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020.

	Unbilled customer revenues(a)
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2021	$	1,178	$	671	$	161	$	102	$	126	$	118	$	58	$	38	$	22
December 31, 2020	998		258		218		147		197		178		87		62		29

_________

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

Sales of Customer Accounts Receivable (Exelon and Generation)

On April 8, 2020, NER, a bankruptcy remote, special purpose entity, which is wholly-owned by Generation, entered into a revolving accounts receivable financing arrangement with a number of financial institutions and a commercial paper conduit (the Purchasers) to sell certain customer accounts receivable (the Facility). The Facility had a maximum funding limit of $750 million and was scheduled to expire on April 7, 2021, unless renewed by the mutual consent of the parties in accordance with its terms. The Facility was renewed on March 29, 2021. The Facility term was extended through March 29, 2024, unless further renewed by the mutual consent of the parties, and the maximum funding limit was increased to $900 million. Under the Facility, NER may sell eligible short-term customer accounts receivable to the Purchasers in exchange for cash and subordinated interest. The transfers are reported as sales of receivables in Exelon’s and Generation’s consolidated financial statements. The subordinated interest in collections upon the receivables sold to the Purchasers is referred to as the DPP, which is reflected in Other current assets on Exelon’s and Generation’s Consolidated Balance Sheets.

On April 8, 2020, Generation derecognized and transferred approximately $1.2 billion of receivables at fair value to the Purchasers in exchange for approximately $500 million in cash purchase price and $650 million of DPP.

On February 17, 2021, Generation received additional cash of $250 million from the Purchasers for the remaining available funding in the Facility.

On March 31, 2021, Generation received cash of approximately $150 million from the Purchasers in connection with the increased funding limit at the time of the Facility renewal.

The following table summarizes the impact of the sale of certain receivables:

	March 31, 2021		December 31, 2020
Derecognized receivables transferred at fair value	$	1,301	$	1,139
Cash proceeds received	900		500
DPP	401		639

	Three Months Ended March 31, 2021
Loss on sale of receivables(a)	$	17

_________

(a)Reflected in Operating and maintenance expense on Exelon's and Generation's Consolidated Statement of Operations and Comprehensive Income.

	Three Months Ended March 31, 2021
Proceeds from new transfers(a)	$	1,036
Cash collections received on DPP and reinvested in the Facility(b)	1,174
Cash collections reinvested in the Facility	2,210

_________

(a)Customer accounts receivable sold into the Facility were $2,375 million for the three months ended March 31, 2021.

(b)Does not include the $400 million in cash proceeds received from the Purchasers in the first quarter of 2021.

Generation’s risk of loss following the transfer of accounts receivable is limited to the DPP outstanding.  Payment of DPP is not subject to significant risks other than delinquencies and credit losses on accounts receivable transferred, which have historically been and are expected to be immaterial. Generation continues to service the receivables sold in exchange for a servicing fee. Generation did not record a servicing asset or liability as the servicing fees were immaterial.

Generation recognizes the cash proceeds received upon sale in Net cash provided by operating activities in the Consolidated Statement of Cash Flows. The collection and reinvestment of DPP is recognized in Net cash provided by investing activities of the Consolidated Statement of Cash Flows.

See Note 13 — Fair Value of Financial Assets and Liabilities and Note 16 — Variable Interest Entities for additional information.

Other Purchases and Sales of Customer and Other Accounts Receivables (All Registrants)

Generation is required, under supplier tariffs in ISO-NE, MISO, NYISO, and PJM, to sell customer and other receivables to utility companies, which include the Utility Registrants. The Utility Registrants are required, under separate legislation and regulations in Illinois, Pennsylvania, Maryland, District of Columbia, and New Jersey, to purchase certain receivables from alternative retail electric and, as applicable, natural gas suppliers that participate in the utilities' consolidated billing. The following tables present the total receivables purchased and sold.

	Three Months Ended March 31, 2021
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Total receivables purchased	$	1,011	$	—	$	266	$	290	$	199	$	268	$	166	$	56	$	46
Total receivables sold	69		81		—		—		—		—		—		—		—
Related party transactions:
Receivables purchased from Generation	—		—		—		—		12		—		—		—		—
Receivables sold to the Utility Registrants	—		12		—		—		—		—		—		—		—

	Three Months Ended March 31, 2020
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Total receivables purchased	$	781	$	—	$	280	$	284	$	195	$	264	$	165	$	53	$	46
Total receivables sold	507		749		—		—		—		—		—		—		—
Related party transactions:
Receivables purchased from Generation	—		—		34		67		69		72		51		13		8
Receivables sold to the Utility Registrants	—		242		—		—		—		—		—		—		—

XML

Early Plant Retirements (Exelon and Generation)

3 Months Ended

Mar. 31, 2021

Property, Plant and Equipment [Abstract]

Early Plant Retirements (Exelon and Generation)

Early Plant Retirements (Exelon and Generation)

Exelon and Generation continuously evaluate factors that affect the current and expected economic value of Generation’s plants, including, but not limited to: market power prices, results of capacity auctions, potential legislative and regulatory solutions to ensure plants are fairly compensated for benefits they provide through their carbon-free emissions, reliability, or fuel security, and the impact of potential rules from the EPA requiring reduction of carbon and other emissions and the efforts of states to implement those final rules. The precise timing of an early retirement date for any plant, and the resulting financial statement impacts, may be affected by many factors, including the status of potential regulatory or legislative solutions, results of any transmission system reliability study assessments, the nature of any co-owner requirements and stipulations, and NDT fund requirements for nuclear plants, among other factors. However, the earliest retirement date for any plant would usually be the first year in which the unit does not have capacity or other obligations, and where applicable, just prior to its next scheduled nuclear refueling outage.

Nuclear Generation

In 2015 and 2016, Generation identified the Clinton and Quad Cities nuclear plants in Illinois, Ginna and Nine Mile Point nuclear plants in New York, and TMI nuclear plant in Pennsylvania as having the greatest risk of early retirement based on economic valuation and other factors. In 2017, PSEG made public similar financial challenges facing its New Jersey nuclear plants, including Salem, of which Generation owns a 42.59% ownership interest. PSEG is the operator of Salem and also has the decision-making authority to retire Salem.

Assuming the continued effectiveness of the Illinois ZES, New Jersey ZEC program, and the New York CES, Generation and CENG, through its ownership of Ginna and Nine Mile Point, no longer consider Clinton, Quad Cities, Salem, Ginna, or Nine Mile Point to be at heightened risk for early retirement. However, to the extent the Illinois ZES, New Jersey ZEC program, or the New York CES do not operate as expected over their full terms, each of these plants, in addition to FitzPatrick, would be at heightened risk for early retirement, which could have a material impact on Exelon’s and Generation’s future financial statements. In addition, FERC’s December 19, 2019 order on the MOPR in PJM may undermine the continued effectiveness of the Illinois ZES and the New

Jersey ZEC program unless Illinois and New Jersey implement an FRR mechanism under which the Generation plants in these states would be removed from PJM’s capacity auction. See Note 3 — Regulatory Matters for additional information on the New Jersey ZEC program and Note 3 — Regulatory Matters of the 2020 Form 10-K for additional information on the Illinois ZES, New York CES, and FERC's December 19, 2019 order on the MOPR in PJM.

Generation’s Dresden, Byron, and Braidwood nuclear plants in Illinois are also showing increased signs of economic distress, in a market that does not currently compensate them for their unique contribution to grid resiliency and their ability to produce large amounts of energy without carbon and air pollution. The May 2018 PJM capacity auction for the 2021-2022 planning year resulted in the largest volume of nuclear capacity ever not selected in the auction, including all of Dresden, and portions of Byron and Braidwood. While all of LaSalle's capacity did clear in the 2021-2022 planning year auction, Generation has become increasingly concerned about the economic viability of this plant as well in a landscape where energy market prices remain depressed and energy market rules remain fatally flawed.

On August 27, 2020, Generation announced that it intends to permanently cease generation operations at Byron in September 2021 and at Dresden in November 2021. The current NRC licenses for Byron Units 1 and 2 expire in 2044 and 2046, respectively, and the licenses for Dresden Units 2 and 3 expire in 2029 and 2031, respectively.

As a result of the decision to early retire Byron and Dresden, Exelon and Generation recognized certain one-time charges in the third and fourth quarters of 2020 related to materials and supplies inventory reserve adjustments, employee-related costs including severance benefit costs further discussed below, and construction work-in-progress impairments, among other items. In addition, as a result of the decisions to early retire Byron and Dresden, there are ongoing annual financial impacts stemming from shortening the expected economic useful lives of these nuclear plants primarily related to accelerated depreciation of plant assets (including any ARC), accelerated amortization of nuclear fuel, and changes in ARO accretion expense associated with the changes in decommissioning timing and cost assumptions to reflect an earlier retirement date. The total impact for the three months ended March 31, 2021 on Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income is summarized in the table below.

Income statement expense (pre-tax)	Three Months Ended March 31, 2021(a)
Depreciation and amortization
Accelerated depreciation(a)	$	620
Accelerated nuclear fuel amortization	54
Operating and maintenance
Other charges	2
Contractual offset(b)	(226)
Total	$	450

_________

(a)Includes the accelerated depreciation of plant assets including any ARC.

(b)Reflects contractual offset for ARO accretion and ARC depreciation. Based on the regulatory agreement with the ICC, decommissioning-related activities in the first quarter of 2021 have been offset within Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. The offset in 2021 resulted in an equal adjustment to the noncurrent payables to ComEd at Generation and an adjustment to the regulatory liabilities at ComEd. See Note 10 - Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information.

Severance benefit costs will be provided to employees impacted by the early retirements of Byron and Dresden, to the extent they are not redeployed to other nuclear plants. In 2020, Exelon and Generation recorded estimated severance expense of $81 million within Operating and maintenance expense in their Consolidated Statements of Operations and Comprehensive Income. The severance liability was $81 million as of March 31, 2021 on Exelon's and Generation's Consolidated Balance Sheets. The final amount of severance benefit costs will depend on the specific employees severed.

The following table provides the balance sheet amounts as of March 31, 2021 for Exelon's and Generation's significant assets and liabilities associated with the Braidwood and LaSalle nuclear plants. Current depreciation provisions are based on the estimated useful lives of these nuclear generating stations, which reflect the first renewal of the operating licenses.

	Braidwood		LaSalle		Total
Asset Balances
Materials and supplies inventory, net	$	83	$	103	$	186
Nuclear fuel inventory, net	165		264		429
Completed plant, net	1,379		1,566		2,945
Construction work in progress	33		70		103
Liability Balances
Asset retirement obligation	(577)		(964)		(1,541)
NRC License First Renewal Term	2046 (Unit 1)		2042 (Unit 1)
	2047 (Unit 2)		2043 (Unit 2)

Exelon continues to work with stakeholders on state policy solutions, while also advocating for broader market reforms at the regional and federal level. The absence of such solutions or reforms could result in future impairments of the Midwest asset group, or accelerated depreciation for specific plants over their shortened estimated useful lives, both of which could have a material unfavorable impact on Exelon's and Generation's future results of operations.

Other Generation

In March 2018, Generation notified ISO-NE of its plans to early retire, among other assets, the Mystic Generating Station's units 8 and 9 (Mystic 8 and 9) absent regulatory reforms to properly value reliability and regional fuel security. Thereafter, ISO-NE identified Mystic 8 and 9 as being needed to ensure fuel security for the region and entered into a cost of service agreement with these two units for the period between June 1, 2022 - May 31, 2024. The agreement was approved by the FERC in December 2018.

On June 10, 2020, Generation filed a complaint with FERC against ISO-NE stating that ISO-NE failed to follow its tariff with respect to its evaluation of Mystic 8 and 9 for transmission security for the 2024 to 2025 Capacity Commitment Period and that the modifications that ISO-NE made to its unfiled planning procedures to avoid retaining Mystic 8 and 9 should have been filed with FERC for approval. On August 17, 2020, FERC issued an order denying the complaint. As a result, on August 20, 2020, Exelon determined that Generation will permanently cease generation operations at Mystic 8 and 9 at the expiration of the cost of service commitment in May 2024. See Note 3 — Regulatory Matters for additional discussion of Mystic’s cost of service agreement.

As a result of the decision to early retire Mystic 8 and 9, there are financial impacts stemming from shortening the expected economic useful life of Mystic 8 and 9 primarily related to accelerated depreciation of plant assets. Exelon and Generation recorded incremental Depreciation and amortization expense of $20 million for the three months ended March 31, 2021.

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Nuclear Decommissioning (Exelon and Generation)

3 Months Ended

Mar. 31, 2021

Asset Retirement Obligation Disclosure [Abstract]

Nuclear Decommissioning (Exelon and Generation)

Nuclear Decommissioning (Exelon and Generation)

Nuclear Decommissioning Asset Retirement Obligations

Generation has a legal obligation to decommission its nuclear power plants following the expiration of their operating licenses. To estimate its decommissioning obligation related to its nuclear generating stations for

financial accounting and reporting purposes, Generation uses a probability-weighted, discounted cash flow model which, on a unit-by-unit basis, considers multiple outcome scenarios that include significant estimates and assumptions, and are based on decommissioning cost studies, cost escalation rates, probabilistic cash flow models, and discount rates. Generation updates its ARO annually, unless circumstances warrant more frequent updates, based on its review of updated cost studies and its annual evaluation of cost escalation factors and probabilities assigned to various scenarios.

The financial statement impact for changes in the ARO, on an individual unit basis, due to the changes in and timing of estimated cash flows generally result in a corresponding change in the unit’s ARC within Property, plant, and equipment on Exelon’s and Generation’s Consolidated Balance Sheets. If the ARO decreases for a Non-Regulatory Agreement unit without any remaining ARC, the corresponding change is recorded as decrease in Operating and maintenance expense within Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income.

The following table provides a rollforward of the nuclear decommissioning ARO reflected in Exelon’s and Generation’s Consolidated Balance Sheets from December 31, 2020 to March 31, 2021:

Nuclear decommissioning ARO at December 31, 2020(a)	$	11,922
Accretion expense	124
Costs incurred related to decommissioning plants	(20)
Nuclear decommissioning ARO at March 31, 2021(a)	$	12,026

_________

(a)Includes $80 million as the current portion of the ARO at March 31, 2021 and December 31, 2020, which is included in Other current liabilities in Exelon’s and Generation’s Consolidated Balance Sheets.

NDT Funds

Exelon and Generation had NDT funds totaling $14,927 million and $14,599 million at March 31, 2021 and December 31, 2020, respectively. The NDT funds also include $239 million and $134 million for the current portion of the NDT funds at March 31, 2021 and December 31, 2020, respectively, which are included in Other current assets in Exelon's and Generation's Consolidated Balance Sheets. See Note 17 — Supplemental Financial Information for additional information on activities of the NDT funds.

NRC Minimum Funding Requirements

NRC regulations require that licensees of nuclear generating facilities demonstrate reasonable assurance that funds will be available in specified minimum amounts to decommission the facility at the end of its life.

Generation filed its biennial decommissioning funding status report with the NRC on February 24, 2021 for all units, including its shutdown units, except for Zion Station which is included in a separate report to the NRC submitted by ZionSolutions, LLC. The status report demonstrated adequate decommissioning funding assurance as of December 31, 2020 for all units except for Byron Units 1 and 2. Generation stated that it intends to submit its PSDAR with additional decommissioning cost information by July 1, 2021, for Byron Units 1 and 2, and will evaluate the status of funding assurance based on the updated cost information and provide additional funding assurance by the time of shutdown if required.

Generation will file its next decommissioning funding status report with the NRC by March 31, 2022. This report will reflect the status of decommissioning funding assurance as of December 31, 2021 for shutdown units.

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Income Taxes (All Registrants)

3 Months Ended

Mar. 31, 2021

Income Tax Disclosure [Abstract]

Income Taxes (All Registrants)

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 March 31, 2021
	Exelon(a)	Generation(a)	ComEd(b)	PECO(b)	BGE(b),(c)	PHI(b)	Pepco(b)	DPL(b)	ACE(b)
U.S. Federal statutory rate	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	14.6	4.4	6.8	(1.6)	(10.1)	6.1	5.5	6.4	6.9
Qualified NDT fund income	(18.4)	(5.5)	—	—	—	—	—	—	—
Amortization of investment tax credit, including deferred taxes on basis difference	2.4	0.6	(0.1)	—	(0.1)	(0.1)	—	(0.2)	(0.2)
Plant basis differences	8.8	—	(0.6)	(10.5)	(1.4)	(1.5)	(2.1)	(0.7)	(0.9)
Production tax credits and other credits	6.7	1.8	(0.2)	—	(0.4)	(0.2)	(0.2)	(0.1)	(0.3)
Noncontrolling interests	0.6	0.2	—	—	—	—	—	—	—
Excess deferred tax amortization	27.9	—	(6.9)	(3.2)	(15.5)	(19.3)	(15.1)	(18.5)	(28.7)
Other(d)	(56.9)	(3.6)	(3.5)	(0.1)	(0.1)	(0.1)	0.1	0.3	2.2
Effective income tax rate	6.7%	18.9%	16.5%	5.6%	(6.6)%	5.9%	9.2%	8.2%	—%

	Three Months Ended March 31, 2020
	Exelon(b)	Generation(e)	ComEd(b)	PECO(b)	BGE(b)	PHI(b)	Pepco(b)	DPL(b)	ACE(b)
U.S. Federal statutory rate	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	34.0	0.7	8.3	0.1	5.7	5.8	4.7	6.6	6.7
Qualified NDT fund income	(235.8)	36.4	—	—	—	—	—	—	—
Amortization of investment tax credit, including deferred taxes on basis difference	(4.5)	0.5	(0.2)	—	(0.1)	(0.1)	—	(0.2)	(0.2)
Plant basis differences	(23.0)	—	(1.1)	(8.4)	(1.2)	(1.4)	(2.1)	(0.7)	(0.8)
Production tax credits and other credits	(9.9)	1.3	(0.2)	—	(0.2)	—	—	—	—
Noncontrolling interests	10.6	(1.6)	—	—	—	—	—	—	—
Excess deferred tax amortization	(71.7)	—	(10.5)	(3.0)	(7.3)	(15.5)	(14.2)	(12.7)	(18.8)
Tax Settlements	(79.1)	12.2	—	—	—	—	—	—	—
Other	12.5	0.6	0.3	—	0.6	(0.6)	(0.6)	(0.5)	(0.8)
Effective income tax rate	(345.9)%	71.1%	17.6%	9.7%	18.5%	9.2%	8.8%	13.5%	7.1%

__________

(a)Exelon and Generation recognized a loss before income taxes for the quarter ended March 31, 2021. As a result, positive percentages represent an income tax benefit for the period presented.

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

(c)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.

(d)For Exelon, "Other" is primarily driven by the consolidating income tax adjustment recorded at Exelon Corporate in the first quarter of 2021 that was required pursuant to GAAP interim reporting guidance. This incremental expense will reverse by year-end and will not have an impact on annual results.

(e)Generation recognized a loss before income taxes for the quarter ended March 31, 2020. As a result, positive percentages represent an income tax benefit for the period presented.

Unrecognized Tax Benefits

PHI and ACE have the following unrecognized tax benefits as of March 31, 2021 and December 31, 2020. Exelon's, Generation's, ComEd's, PECO's, BGE's, Pepco's, and DPL's amounts are not material.

	PHI		ACE
March 31, 2021	$	52	$	15
December 31, 2020	52		15

Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date

As of March 31, 2021, ACE has approximately $14 million of unrecognized state tax benefits that could significantly decrease within the 12 months after the reporting date based on the outcome of pending court cases involving other taxpayers. The unrecognized tax benefit, if recognized, may be included in future base rates and that portion would have no impact to the effective tax rate.

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Retirement Benefits (All Registrants)

3 Months Ended

Mar. 31, 2021

Retirement Benefits [Abstract]

Retirement Benefits (All Registrants)

Retirement Benefits (All Registrants)

Defined Benefit Pension and OPEB

During the first quarter of 2021, Exelon received an updated valuation of its pension and OPEB to reflect actual census data as of January 1, 2021. This valuation resulted in an increase to the pension obligations of $33 million and a decrease to the OPEB obligations of $9 million. Additionally, accumulated other comprehensive loss increased by $1 million (after-tax) and regulatory assets and liabilities increased by $21 million and $1 million, respectively.

The majority of the 2021 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 2.58%. The majority of the 2021 OPEB cost is calculated using an expected long-term rate of return on plan assets of 6.46% for funded plans and a discount rate of 2.51%.

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 months ended March 31, 2021 and 2020.

	Pension Benefits				OPEB
	Three Months Ended March 31,				Three Months Ended March 31,
	2021		2020		2021		2020
Components of net periodic benefit cost:
Service cost	$	110	$	97	$	21	$	23
Interest cost	161		189		28		38
Expected return on assets	(336)		(318)		(40)		(41)
Amortization of:
Prior service cost (credit)	1		1		(8)		(31)
Actuarial loss	150		128		9		12
Curtailment benefits	—		—		(1)		—
Net periodic benefit cost	$	86	$	97	$	9	$	1

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 Generation and the Utility Registrants, the service cost and non-service cost components are included in Operating and maintenance expense and Property, plant, and equipment, net in their consolidated financial statements.

	Three Months Ended March 31,
Pension and OPEB Costs	2021		2020
Exelon	$	95	$	98
Generation	26		27
ComEd	32		28
PECO	2		1
BGE	15		16
PHI	12		17
Pepco	2		3
DPL	1		1
ACE	3		3

Defined Contribution Savings Plans

The Registrants participate in various 401(k) defined contribution savings plans that are sponsored by Exelon. The plans are 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 matching contributions to the savings plans for the three months ended March 31, 2021 and 2020, respectively.

	Three Months Ended March 31,
Savings Plans Matching Contributions	2021		2020
Exelon	$	33	$	33
Generation	13		13
ComEd	8		7
PECO	3		3
BGE	2		2
PHI	3		3
Pepco	1		1
DPL	1		1

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Derivative Financial Instruments (All Registrants)

3 Months Ended

Mar. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Financial Instruments (All Registrants)

Derivative Financial Instruments (All Registrants)

The Registrants use derivative instruments to manage commodity price risk, interest rate risk, and foreign exchange risk related to ongoing business operations.

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. All derivative economic hedges related to commodities, referred to as economic hedges, are recorded at fair value through earnings at Generation and are offset by a corresponding regulatory asset or liability at ComEd. 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.

Authoritative guidance about offsetting assets and liabilities requires the fair value of derivative instruments to be shown in the Combined Notes to Consolidated Financial Statements on a gross basis, even when the derivative instruments are subject to legally enforceable master netting agreements and qualify for net presentation in the Consolidated Balance Sheets. A master netting agreement is an agreement between two counterparties that may have derivative and non-derivative contracts with each other providing for the net settlement of all referenced contracts via one payment stream, which takes place as the contracts deliver, when collateral is requested or in the event of default. In the tables below, which present fair value balances, Generation’s energy-related economic hedges and proprietary trading derivatives are shown gross. The impact of the netting of fair value balances with the same counterparty that are subject to legally enforceable master netting agreements, as well as netting of cash collateral, including margin on exchange positions, is aggregated in the collateral and netting columns.

Generation’s and ComEd’s use of cash collateral is generally unrestricted unless Generation or ComEd are 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 (All Registrants)

Each of the Registrants employ established policies and procedures to manage their risks associated with market fluctuations in commodity prices by entering into physical and financial derivative contracts, including swaps, futures, forwards, options, and short-term and long-term commitments to purchase and sell energy and commodity products. The Registrants believe these instruments, which are either determined to be non-derivative or classified as economic hedges, mitigate exposure to fluctuations in commodity prices.

Generation. To the extent the amount of energy Generation produces differs from the amount of energy it has contracted to sell, Exelon and Generation are exposed to market fluctuations in the prices of electricity, fossil fuels, and other commodities. Within Exelon, Generation has the most exposure to commodity price risk. As such, Generation uses a variety of derivative and non-derivative instruments to manage the commodity price risk of its electric generation facilities, including power and gas sales, fuel and power purchases, natural gas transportation and pipeline capacity agreements, and other energy-related products marketed and purchased. To manage these risks, Generation may enter into fixed-price derivative or non-derivative contracts to hedge the variability in future cash flows from expected sales of power and gas and purchases of power and fuel. The objectives for executing such hedges include fixing the price for a portion of anticipated future electricity sales at a level that provides an acceptable return. Generation is also exposed to differences between the locational settlement prices of certain economic hedges and the hedged generating units. This price difference is actively managed through other instruments which include derivative congestion products, whose changes in fair value are recognized in earnings each period, and auction revenue rights, which are accounted for on an accrual basis.

Additionally, Generation is exposed to certain market risks through its proprietary trading activities. The proprietary trading activities are a complement to Generation’s energy marketing portfolio but represent a small portion of Generation’s overall energy marketing activities and are subject to limits established by Exelon’s RMC.

Utility Registrants. The Utility Registrants procure electric and natural gas supply through a competitive procurement process approved by each of the respective state utility commissions. The Utility Registrants’

hedging programs are intended to reduce exposure to energy and natural gas price volatility and have no direct earnings impact as the costs are fully recovered from customers through 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 2020 Form 10-K for additional information.

(b)The fair value of the DPL economic hedge is not material as of March 31, 2021 and December 31, 2020 and is not presented in the fair value tables below.

The following table provides a summary of the derivative fair value balances recorded by Exelon, Generation, and ComEd as of March 31, 2021 and December 31, 2020:

	Exelon		Generation										ComEd
March 31, 2021	Total Derivatives		Economic Hedges		Proprietary Trading		Collateral(a)(b)		Netting(a)		Subtotal		Economic Hedges
Mark-to-market derivative assets (current assets)	$	569	$	2,566	$	28	$	24	$	(2,049)	$	569	$	—
Mark-to-market derivative assets (noncurrent assets)	488		1,400		5		45		(962)		488		—
Total mark-to-market derivative assets	1,057		3,966		33		69		(3,011)		1,057		—
Mark-to-market derivative liabilities (current liabilities)	(418)		(2,472)		(13)		49		2,049		(387)		(31)
Mark-to-market derivative liabilities (noncurrent liabilities)	(454)		(1,179)		(1)		28		962		(190)		(264)
Total mark-to-market derivative liabilities	(872)		(3,651)		(14)		77		3,011		(577)		(295)
Total mark-to-market derivative net assets (liabilities)	$	185	$	315	$	19	$	146	$	—	$	480	$	(295)

	Exelon		Generation										ComEd
December 31, 2020	Total Derivatives		Economic Hedges		Proprietary Trading		Collateral(a)(b)		Netting(a)		Subtotal		Economic Hedges
Mark-to-market derivative assets (current assets)	$	639	$	2,757	$	40	$	103	$	(2,261)	$	639	$	—
Mark-to-market derivative assets (noncurrent assets)	554		1,501		4		64		(1,015)		554		—
Total mark-to-market derivative assets	1,193		4,258		44		167		(3,276)		1,193		—
Mark-to-market derivative liabilities (current liabilities)	(293)		(2,629)		(23)		131		2,261		(260)		(33)
Mark-to-market derivative liabilities (noncurrent liabilities)	(472)		(1,335)		(2)		118		1,015		(204)		(268)
Total mark-to-market derivative liabilities	(765)		(3,964)		(25)		249		3,276		(464)		(301)
Total mark-to-market derivative net assets (liabilities)	$	428	$	294	$	19	$	416	$	—	$	729	$	(301)

_________

(a)Exelon and Generation net all available amounts allowed under the derivative authoritative guidance in the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases Exelon and Generation may have other offsetting exposures, subject to a master netting or similar agreement, such as trade receivables and payables, transactions that do not qualify as derivatives, letters of credit, and other forms of non-cash collateral. These amounts are not material and not reflected in the table above.

(b)Of the collateral posted, $148 million and $209 million represents variation margin on the exchanges as of March 31, 2021 and December 31, 2020 respectively.

Economic Hedges (Commodity Price Risk)

Generation. For the three months ended March 31, 2021 and 2020, Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses) which are also located in the Net fair value changes related to derivatives line in the Consolidated Statements of Cash Flows.

	Three Months Ended March 31,
	2021		2020
Income Statement Location	Gain (Loss)
Operating revenues	$	(83)	$	175
Purchased power and fuel	265		(47)
Total Exelon and Generation	$	182	$	128

In general, increases and decreases in forward market prices have a positive and negative impact, respectively, on Generation’s owned and contracted generation positions that have not been hedged. Generation hedges commodity price risk on a ratable basis over three-year periods. As of March 31, 2021, the percentage of expected generation hedged for the Mid-Atlantic, Midwest, New York, and ERCOT reportable segments is 94%-97% for 2021.

Proprietary Trading (Commodity Price Risk)

Generation also executes commodity derivatives for proprietary trading purposes. Proprietary trading includes all contracts executed with the intent of benefiting from shifts or changes in market prices as opposed to those executed with the intent of hedging or managing risk. Gains and losses associated with proprietary trading are reported as Operating revenues in Exelon’s and Generation’s Consolidated Statements of Operations and Comprehensive Income and are included in the Net fair value changes related to derivatives line in the Consolidated Statements of Cash Flows. For the three months ended March 31, 2021 and 2020, net pre-tax commodity mark-to-market gains and losses for Exelon and Generation were not material. The Utility Registrants do not execute derivatives for proprietary trading purposes.

Interest Rate and Foreign Exchange Risk (Exelon and Generation)

Generation utilizes interest rate swaps to manage its interest rate exposure and foreign currency derivatives to manage foreign exchange rate exposure associated with international commodity purchases in currencies other than U.S. dollars, both of which are treated as economic hedges. The notional amounts were $563 million and $665 million for Exelon and Generation as of March 31, 2021 and December 31, 2020, respectively.

The mark-to-market derivative assets and liabilities as of March 31, 2021 and December 31, 2020 and the mark-to-market gains and losses for the three months ended March 31, 2021 and 2020 were not material for Exelon and Generation.

Credit Risk (All Registrants)

The Registrants would be exposed to credit-related losses in the event of non-performance by counterparties on executed derivative instruments. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date.

Generation. For commodity derivatives, Generation enters into enabling agreements that allow for payment netting with its counterparties, which reduces Generation’s exposure to counterparty risk by providing for the offset of amounts payable to the counterparty against amounts receivable from the counterparty. Typically, each enabling agreement is for a specific commodity and so, with respect to each individual counterparty, netting is limited to transactions involving that specific commodity product, except where master netting agreements exist with a counterparty that allow for cross product netting. In addition to payment netting language in the enabling agreement, Generation’s credit department establishes credit limits, margining thresholds, and collateral requirements for each counterparty, which are defined in the derivative contracts. Counterparty credit limits are based on an internal credit review process that considers a variety of factors, including the results of a scoring model, leverage, liquidity, profitability, credit ratings by credit rating agencies, and risk management capabilities. To the extent that a counterparty’s margining thresholds are exceeded, the counterparty is required to post collateral with Generation as specified in each enabling agreement. Generation’s credit department monitors current and forward credit exposure to counterparties and their affiliates, both on an individual and an aggregate basis.

The following tables provide information on Generation’s credit exposure for all derivative instruments, NPNS, and payables and receivables, net of collateral and instruments that are subject to master netting agreements, as of March 31, 2021. The tables further delineate that exposure by credit rating of the counterparties and provide guidance on the concentration of credit risk to individual counterparties. The amounts in the tables below exclude credit risk exposure from individual retail counterparties, nuclear fuel procurement contracts, and exposure through RTOs, ISOs, NYMEX, ICE, NASDAQ, NGX, and Nodal commodity exchanges. 

Rating as of March 31, 2021	Total Exposure Before Credit Collateral		Credit Collateral(a)		Net Exposure		Number of Counterparties Greater than 10% of Net Exposure	Net Exposure of Counterparties Greater than 10% of Net Exposure
Investment grade	$	431	$	31	$	400	—	$	—
Non-investment grade	43		4		39
No external ratings
Internally rated — investment grade	146		1		145
Internally rated — non-investment grade	70		25		45
Total	$	690	$	61	$	629	—	$	—

Net Credit Exposure by Type of Counterparty	As of March 31, 2021
Investor-owned utilities, marketers, power producers	$	451
Energy cooperatives and municipalities	123
Other	55
Total	$	629

_________ 

(a)As of March 31, 2021, credit collateral held from counterparties where Generation had credit exposure included $32 million of cash and $29 million of letters of credit. The credit collateral does not include non-liquid collateral.

Utility Registrants. The Utility Registrants have contracts to procure electric and natural gas supply that provide suppliers with a certain amount of unsecured credit. If the exposure on the supply contract exceeds the amount of unsecured credit, the suppliers may be required to post collateral. The net credit exposure is mitigated primarily by the ability to recover procurement costs through customer rates. As of March 31, 2021, the Utility Registrants’ counterparty credit risk with suppliers was not material.

Credit-Risk-Related Contingent Features (All Registrants)

Generation. As part of the normal course of business, Generation routinely enters into physically or financially settled contracts for the purchase and sale of electric capacity, electricity, fuels, emissions allowances, and other energy-related products. Certain of Generation’s derivative instruments contain provisions that require Generation to post collateral. Generation also enters into commodity transactions on exchanges where the exchanges act as the counterparty to each trade. Transactions on the exchanges must adhere to comprehensive collateral and margining requirements. This collateral may be posted in the form of cash or credit support with thresholds contingent upon Generation’s credit rating from each of the major credit rating agencies. The collateral and credit support requirements vary by contract and by counterparty. These credit-risk-related contingent features stipulate that if Generation were to be downgraded or lose its investment grade credit rating (based on its senior unsecured debt rating), it would be required to provide additional collateral. This incremental collateral requirement allows for the offsetting of derivative instruments that are assets with the same counterparty, where the contractual right of offset exists under applicable master netting agreements. In the absence of expressly agreed-to provisions that specify the collateral that must be provided, collateral requested will be a function of the facts and circumstances of the situation at the time of the demand. In this case, Generation believes an amount of several months of future payments (i.e., capacity payments) rather than a calculation of fair value is the best estimate for the contingent collateral obligation, which has been factored into the disclosure below.

The aggregate fair value of all derivative instruments with credit-risk related contingent features in a liability position that are not fully collateralized (excluding transactions on the exchanges that are fully collateralized) is detailed in the table below:

Credit-Risk Related Contingent Features	March 31, 2021		December 31, 2020
Gross fair value of derivative contracts containing this feature(a)	$	(948)	$	(834)
Offsetting fair value of in-the-money contracts under master netting arrangements(b)	518		537
Net fair value of derivative contracts containing this feature(c)	$	(430)	$	(297)

_________

(a)Amount represents the gross fair value of out-of-the-money derivative contracts containing credit-risk related contingent features ignoring the effects of master netting agreements.

(b)Amount represents the offsetting fair value of in-the-money derivative contracts under legally enforceable master netting agreements with the same counterparty, which reduces the amount of any liability for which Generation could potentially be required to post collateral.

(c)Amount represents the net fair value of out-of-the-money derivative contracts containing credit-risk related contingent features after considering the mitigating effects of offsetting positions under master netting arrangements and reflects the actual net liability upon which any potential contingent collateral obligations would be based.

As of March 31, 2021 and December 31, 2020, Exelon and Generation posted or held the following amounts of cash collateral and letters of credit on derivative contracts with external counterparties, after giving consideration to offsetting derivative and non-derivative positions under master netting agreements.

	March 31, 2021		December 31, 2020
Cash collateral posted	$	232	$	511
Letters of credit posted	242		226
Cash collateral held	101		110
Letters of credit held	41		40
Additional collateral required in the event of a credit downgrade below investment grade	1,379		1,432

Generation entered into supply forward contracts with certain utilities, including PECO and BGE, with one-sided collateral postings only from Generation. If market prices fall below the benchmark price levels in these contracts, the utilities are not required to post collateral. However, when market prices rise above the benchmark price levels, counterparty suppliers, including Generation, are required to post collateral once certain unsecured credit limits are exceeded.

Utility Registrants

The Utility Registrants’ electric supply procurement contracts do not contain provisions that would require them to post collateral.

PECO’s, BGE’s, and DPL’s natural gas procurement contracts contain provisions that could require PECO, BGE, and DPL to post collateral in the form of cash or credit support, which vary by contract and counterparty, with thresholds contingent upon PECO’s, BGE's, and DPL’s credit rating. As of March 31, 2021, PECO, BGE, and DPL were not required to post collateral for any of these agreements. If PECO, BGE, or DPL lost their investment grade credit rating as of March 31, 2021, they could have been required to post incremental collateral to its counterparties of $32 million, $48 million and $12 million, respectively.

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Debt and Credit Agreements (All Registrants)

3 Months Ended

Mar. 31, 2021

Debt Disclosure [Abstract]

Debt and Credit Agreements (All Registrants)

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. Generation and PECO meet 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 the Exelon intercompany money pool. The Registrants may use their respective credit facilities for general corporate purposes, including meeting short-term funding requirements and the issuance of letters of credit.

Commercial Paper

The following table reflects the Registrants' commercial paper programs as of March 31, 2021 and December 31, 2020. PECO had no commercial paper borrowings as of both March 31, 2021 and December 31, 2020.

	Outstanding Commercial Paper as of				Average Interest Rate on Commercial Paper Borrowings as of
Commercial Paper Issuer	March 31, 2021		December 31, 2020		March 31, 2021		December 31, 2020
Exelon(a)(b)	$	1,628	$	1,031	0.52	%	0.25	%
Generation(b)	1,337		340		0.60	%	0.27	%
ComEd	135		323		0.16	%	0.23	%
BGE	156		—		0.15	%	—	%
PHI(c)	—		368		—	%	0.24	%
Pepco	—		35		—	%	0.22	%
DPL	—		146		—	%	0.24	%
ACE	—		187		—	%	0.25	%

__________

(a)Exelon Corporate had no outstanding commercial paper borrowings as of both March 31, 2021 and December 31, 2020.

(b)Higher outstanding commercial paper primarily driven by increased liquidity needs from the February 2021 extreme cold weather event. See Note 3 – Regulatory Matters for additional information.

(c)Represents the consolidated amounts of Pepco, DPL, and ACE.

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 17, 2021 and will expire on March 16, 2022. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR 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 24, 2021, Exelon Corporate entered into a 9-month term loan agreement for $200 million. The loan agreement has an expiration of December 24, 2021. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR 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 9-month and 364-day term loan agreement for $150 million each with variable interest rates of LIBOR plus 0.65% and expiration dates of December 31, 2021 and March 30, 2022, respectively. The loan agreements are reflected in Exelon's Consolidated Balance Sheets within Short-term borrowings.

On March 19, 2020, Generation entered into a term loan agreement for $200 million. The loan agreement was renewed on March 17, 2021 and will expire on March 16, 2022. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR plus 0.875% and all indebtedness thereunder is unsecured. The loan agreement is reflected in Exelon's and Generation's Consolidated Balance Sheets within Short-term borrowings.

On March 31, 2020, Generation entered into a term loan agreement for $300 million. The loan agreement was renewed on March 30, 2021 and will expire on March 29, 2022. Pursuant to the loan agreement, loans made thereunder bear interest at a variable rate equal to LIBOR plus 0.70% and all indebtedness thereunder is unsecured. The loan agreement is reflected in Exelon's and Generation's Consolidated Balance Sheets within Short-term borrowings.

On January 25, 2021, ComEd entered into two 90-day term loan agreements for $125 million each with variable interest rates of LIBOR plus 0.50% and LIBOR plus 0.75%, respectively. ComEd repaid the term loans on March 9, 2021.

Bilateral Credit Agreements

On January 11, 2013, Generation entered into a bilateral credit agreement for $100 million. The agreement was renewed on March 1, 2021 with a maturity date of March 1, 2023.

On February 21, 2019, Generation entered into a bilateral credit agreement for $100 million. The agreement was renewed on March 31, 2021 with a maturity date of March 31, 2022.

On January 5, 2016, Generation entered into a bilateral credit agreement for $150 million. The agreement was renewed on April 2, 2021 with a maturity date of April 5, 2023.

Long-Term Debt

Issuance of Long-Term Debt

During the three months ended March 31, 2021, the following long-term debt was issued:

Company	Type	Interest Rate		Maturity	Amount		Use of Proceeds
Exelon	Long-Term Software License Agreements	3.62	%	December 1, 2025	$	4	Procurement of software licenses.
Generation	Energy Efficiency Project Financing(a)	2.53	%	May 31, 2021	1		Funding to install energy conservation measures for the Fort AP Hill project.
ComEd	First Mortgage Bonds, Series 130	3.13	%	March 15, 2051	700		Repay a portion of outstanding commercial paper obligations and two outstanding term loans, and to fund other general corporate purposes.
PECO	First and Refunding Mortgage Bonds	3.05	%	March 15, 2051	375		Funding for general corporate purposes.
Pepco(b)	First Mortgage Bonds	2.32	%	March 30, 2031	150		Repay existing indebtedness and for general corporate purposes.
DPL	First Mortgage Bonds	3.24	%	March 30, 2051	125		Repay existing indebtedness and for general corporate purposes.
ACE	First Mortgage Bonds	2.30	%	March 15, 2031	350		Refinance existing indebtedness, repay outstanding commercial paper obligations, and for general corporate purposes.

__________

(a)For Energy Efficiency Project Financing, the maturity dates represent the expected date of project completion, upon which the respective customer assumes the outstanding debt.

(b)On March 30, 2021, Pepco entered into a purchase agreement of First Mortgage Bonds of $125 million at 3.29% due on September 28, 2051. The closing date of the issuance is expected to occur in September 2021.

Debt Covenants

As of March 31, 2021, the Registrants are in compliance with debt covenants.

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Fair Value of Financial Assets and Liabilities (All Registrants)

3 Months Ended

Mar. 31, 2021

Fair Value Disclosures [Abstract]

Fair Value of Financial Assets and Liabilities (All Registrants)

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, SNF obligation, and trust preferred securities (long-term debt to financing trusts or junior subordinated debentures) as of March 31, 2021 and December 31, 2020. The Registrants have no financial liabilities classified as Level 1.

The carrying amounts of the Registrants’ short-term liabilities as presented on their Consolidated Balance Sheets are representative of their fair value (Level 2) because of the short-term nature of these instruments.

	March 31, 2021								December 31, 2020
	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	$	38,529	$	39,255	$	3,115	$	42,370	$	36,912	$	40,688	$	3,064	$	43,752
Generation	6,060		5,497		1,158		6,655		6,087		5,648		1,208		6,856
ComEd	9,674		10,853		—		10,853		8,983		11,117		—		11,117
PECO	4,125		4,491		50		4,541		3,753		4,553		50		4,603
BGE	3,665		3,991		—		3,991		3,664		4,366		—		4,366
PHI	7,577		6,050		1,907		7,957		7,006		6,099		1,806		7,905
Pepco	3,317		3,112		823		3,935		3,165		3,336		748		4,084
DPL	1,802		1,386		524		1,910		1,677		1,484		455		1,939
ACE	1,718		1,302		560		1,862		1,413		1,018		602		1,620
Long-Term Debt to Financing Trusts(a)
Exelon	$	390	$	—	$	465	$	465	$	390	$	—	$	467	$	467
ComEd	205		—		243		243		205		—		246		246
PECO	184		—		222		222		184		—		221		221
SNF Obligation
Exelon	$	1,208	$	979	$	—	$	979	$	1,208	$	909	$	—	$	909
Generation	1,208		979		—		979		1,208		909		—		909

__________

(a)Includes unamortized debt issuance costs which are not fair valued.

Recurring Fair Value Measurements

The following tables present assets and liabilities measured and recorded at fair value in the Registrants' Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of March 31, 2021 and December 31, 2020:

Exelon and Generation

	Exelon										Generation
As of March 31, 2021	Level 1		Level 2		Level 3		Not subject to leveling		Total		Level 1		Level 2		Level 3		Not subject to leveling		Total
Assets
Cash equivalents(a)	$	968	$	—	$	—	$	—	$	968	$	125	$	—	$	—	$	—	$	125
NDT fund investments
Cash equivalents(b)	509		95		—		—		604		509		95		—		—		604
Equities	4,439		1,574		—		1,555		7,568		4,439		1,574		—		1,555		7,568
Fixed income
Corporate debt(c)	—		1,023		283		—		1,306		—		1,023		283		—		1,306
U.S. Treasury and agencies	2,030		41		—		—		2,071		2,030		41		—		—		2,071
Foreign governments	—		51		—		—		51		—		51		—		—		51
State and municipal debt	—		40		—		—		40		—		40		—		—		40
Other	40		35		—		1,285		1,360		40		35		—		1,285		1,360
Fixed income subtotal	2,070		1,190		283		1,285		4,828		2,070		1,190		283		1,285		4,828
Private credit	—		—		196		617		813		—		—		196		617		813
Private equity	—		—		—		532		532		—		—		—		532		532
Real estate	—		—		—		686		686		—		—		—		686		686
NDT fund investments subtotal(d)(e)	7,018		2,859		479		4,675		15,031		7,018		2,859		479		4,675		15,031
Rabbi trust investments
Cash equivalents	60		—		—		—		60		4		—		—		—		4
Mutual funds	95		—		—		—		95		31		—		—		—		31
Fixed income	—		10		—		—		10		—		—		—		—		—
Life insurance contracts	—		89		35		—		124		—		29		—		—		29
Rabbi trust investments subtotal	155		99		35		—		289		35		29		—		—		64
Investments in equities(f)	177		—		—		—		177		177		—		—		—		177
Commodity derivative assets
Economic hedges	478		1,748		1,740		—		3,966		478		1,748		1,740		—		3,966
Proprietary trading	—		16		17		—		33		—		16		17		—		33
Effect of netting and allocation of collateral(g)(h)	(356)		(1,387)		(1,199)		—		(2,942)		(356)		(1,387)		(1,199)		—		(2,942)
Commodity derivative assets subtotal	122		377		558		—		1,057		122		377		558		—		1,057
DPP consideration	—		401		—		—		401		—		401		—		—		401

	Exelon										Generation
As of March 31, 2021	Level 1		Level 2		Level 3		Not subject to leveling		Total		Level 1		Level 2		Level 3		Not subject to leveling		Total
Total assets	8,440		3,736		1,072		4,675		17,923		7,477		3,666		1,037		4,675		16,855
Liabilities
Commodity derivative liabilities
Economic hedges	(359)		(1,642)		(1,945)		—		(3,946)		(359)		(1,642)		(1,650)		—		(3,651)
Proprietary trading	—		(9)		(5)		—		(14)		—		(9)		(5)		—		(14)
Effect of netting and allocation of collateral(g)(h)	252		1,532		1,304		—		3,088		252		1,532		1,304		—		3,088
Commodity derivative liabilities subtotal	(107)		(119)		(646)		—		(872)		(107)		(119)		(351)		—		(577)
Deferred compensation obligation	—		(146)		—		—		(146)		—		(43)		—		—		(43)
Total liabilities	(107)		(265)		(646)		—		(1,018)		(107)		(162)		(351)		—		(620)
Total net assets	$	8,333	$	3,471	$	426	$	4,675	$	16,905	$	7,370	$	3,504	$	686	$	4,675	$	16,235

	Exelon										Generation
As of December 31, 2020	Level 1		Level 2		Level 3		Not subject to leveling		Total		Level 1		Level 2		Level 3		Not subject to leveling		Total
Assets
Cash equivalents(a)	$	686	$	—	$	—	$	—	$	686	$	124	$	—	$	—	$	—	$	124
NDT fund investments
Cash equivalents(b)	210		95		—		—		305		210		95		—		—		305
Equities	3,886		2,077		—		1,562		7,525		3,886		2,077		—		1,562		7,525
Fixed income
Corporate debt(c)	—		1,485		285		—		1,770		—		1,485		285		—		1,770
U.S. Treasury and agencies	1,871		126		—		—		1,997		1,871		126		—		—		1,997
Foreign governments	—		56		—		—		56		—		56		—		—		56
State and municipal debt	—		101		—		—		101		—		101		—		—		101
Other	—		41		—		961		1,002		—		41		—		961		1,002
Fixed income subtotal	1,871		1,809		285		961		4,926		1,871		1,809		285		961		4,926
Private credit	—		—		212		629		841		—		—		212		629		841
Private equity	—		—		—		504		504		—		—		—		504		504
Real estate	—		—		—		679		679		—		—		—		679		679
NDT fund investments subtotal(d)(e)	5,967		3,981		497		4,335		14,780		5,967		3,981		497		4,335		14,780
Rabbi trust investments
Cash equivalents	60		—		—		—		60		4		—		—		—		4
Mutual funds	91		—		—		—		91		29		—		—		—		29
Fixed income	—		11		—		—		11		—		—		—		—		—
Life insurance contracts	—		87		34		—		121		—		28		—		—		28
Rabbi trust investments subtotal	151		98		34		—		283		33		28		—		—		61
Investments in equities(f)	195		—		—		—		195		195		—		—		—		195
Commodity derivative assets
Economic hedges	745		1,914		1,599		—		4,258		745		1,914		1,599		—		4,258
Proprietary trading	—		17		27		—		44		—		17		27		—		44
Effect of netting and allocation of collateral(g)(h)	(607)		(1,597)		(905)		—		(3,109)		(607)		(1,597)		(905)		—		(3,109)
Commodity derivative assets subtotal	138		334		721		—		1,193		138		334		721		—		1,193
DPP consideration	—		639		—		—		639		—		639		—		—		639
Total assets	7,137		5,052		1,252		4,335		17,776		6,457		4,982		1,218		4,335		16,992
Liabilities
Commodity derivative liabilities
Economic hedges	(682)		(1,928)		(1,655)		—		(4,265)		(682)		(1,928)		(1,354)		—		(3,964)
Proprietary trading	—		(21)		(4)		—		(25)		—		(21)		(4)		—		(25)
Effect of netting and allocation of collateral(g)(h)	540		1,918		1,067		—		3,525		540		1,918		1,067		—		3,525
Commodity derivative liabilities subtotal	(142)		(31)		(592)		—		(765)		(142)		(31)		(291)		—		(464)
Deferred compensation obligation	—		(145)		—		—		(145)		—		(42)		—		—		(42)
Total liabilities	(142)		(176)		(592)		—		(910)		(142)		(73)		(291)		—		(506)
Total net assets	$	6,995	$	4,876	$	660	$	4,335	$	16,866	$	6,315	$	4,909	$	927	$	4,335	$	16,486

__________    

(a)Exelon excludes cash of $1,273 million and $409 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $93 million and $59 million at March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $52 million and $53 million at March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. Generation excludes cash of $608 million and $171 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $29 million and $20 million at March 31, 2021 and December 31, 2020, respectively. 

(b)Includes $108 million and $116 million of cash received from outstanding repurchase agreements at March 31, 2021 and December 31, 2020, respectively, and is offset by an obligation to repay upon settlement of the agreement as discussed in (e) below.

(c)Includes investments in equities sold short of $(58) million and $(62) million as of March 31, 2021 and December 31, 2020, respectively, held in an investment vehicle primarily to hedge the equity option component of its convertible debt.

(d)Includes derivative assets of less than $1 million and $2 million, which have total notional amounts of $2,049 million and $1,043 million at March 31, 2021 and December 31, 2020, respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the periods ended and do not represent the amount of Exelon and Generation's exposure to credit or market loss.

(e)Excludes net liabilities of $104 million and $181 million at March 31, 2021 and December 31, 2020, respectively, which include certain derivative assets that have notional amounts of $158 million and $104 million at March 31, 2021 and December 31, 2020, respectively. These items consist of receivables related to pending securities sales, interest and dividend receivables, repurchase agreement obligations, and payables related to pending securities purchases. The repurchase agreements are generally short-term in nature with durations generally of 30 days or less.

(f)Includes equity investments held by Generation which were previously designated as equity investments without readily determinable fair value but are now publicly traded and therefore have readily determinable fair values. Generation recorded the fair value of these investments in Other current assets on Exelon's and Generation's Consolidated Balance Sheets based on the quoted market prices of the stocks at March 31, 2021 and December 31, 2020, which resulted in unrealized gains of $95 million and $186 million within Other, net in Exelon's and Generation's Consolidated Statement of Operations and Comprehensive Income for the three months ended March 31, 2021 and for the year ended December 31, 2020, respectively.

(g)Collateral (received)/posted from counterparties, net of collateral paid to counterparties, totaled $(104) million, $145 million, and $105 million allocated to Level 1, Level 2, and Level 3 mark-to-market derivatives, respectively, as of March 31, 2021. Collateral (received)/posted from counterparties, net of collateral paid to counterparties, totaled $(67) million, $321 million, and $162 million allocated to Level 1, Level 2, and Level 3 mark-to-market derivatives, respectively, as of December 31, 2020.

(h)Of the collateral (received)/posted, $(148) million and $209 million represents variation margin on the exchanges as of March 31, 2021 and December 31, 2020, respectively.

As of March 31, 2021, Exelon and Generation have outstanding commitments to invest in private credit, private equity, and real estate investments of approximately $298 million, $239 million, and $344 million, respectively. These commitments will be funded by Generation’s existing NDT funds.

Exelon and Generation hold investments without readily determinable fair values with carrying amounts of $61 million and $50 million as of March 31, 2021, respectively. Changes in fair value, cumulative adjustments, and impairments were not material for the three months ended March 31, 2021.

ComEd, PECO, and BGE

	ComEd								PECO								BGE
As of March 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)	$	300	$	—	$	—	$	300	$	7	$	—	$	—	$	7	$	—	$	—	$	—	$	—
Rabbi trust investments
Mutual funds	—		—		—		—		9		—		—		9		11		—		—		11
Life insurance contracts	—		—		—		—		—		13		—		13		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		9		13		—		22		11		—		—		11
Total assets	300		—		—		300		16		13		—		29		11		—		—		11
Liabilities
Deferred compensation obligation	—		(8)		—		(8)		—		(9)		—		(9)		—		(6)		—		(6)
Mark-to-market derivative liabilities(b)	—		—		(295)		(295)		—		—		—		—		—		—		—		—
Total liabilities	—		(8)		(295)		(303)		—		(9)		—		(9)		—		(6)		—		(6)
Total net assets (liabilities)	$	300	$	(8)	$	(295)	$	(3)	$	16	$	4	$	—	$	20	$	11	$	(6)	$	—	$	5

	ComEd								PECO								BGE
As of December 31, 2020	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)	$	285	$	—	$	—	$	285	$	8	$	—	$	—	$	8	$	120	$	—	$	—	$	120
Rabbi trust investments
Mutual funds	—		—		—		—		9		—		—		9		10		—		—		10
Life insurance contracts	—		—		—		—		—		13		—		13		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		9		13		—		22		10		—		—		10
Total assets	285		—		—		285		17		13		—		30		130		—		—		130
Liabilities
Deferred compensation obligation	—		(8)		—		(8)		—		(9)		—		(9)		—		(5)		—		(5)
Mark-to-market derivative liabilities(b)	—		—		(301)		(301)		—		—		—		—		—		—		—		—
Total liabilities	—		(8)		(301)		(309)		—		(9)		—		(9)		—		(5)		—		(5)
Total net assets (liabilities)	$	285	$	(8)	$	(301)	$	(24)	$	17	$	4	$	—	$	21	$	130	$	(5)	$	—	$	125

__________

(a)ComEd excludes cash of $59 million and $83 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $40 million and $37 million at March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $43 million at both March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. PECO excludes cash of $48 million and $18 million at March 31, 2021 and December 31, 2020, respectively. BGE excludes cash of $21 million and $24 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $1 million at both March 31, 2021 and December 31, 2020.

(b)The Level 3 balance consists of the current and noncurrent liability of $31 million and $264 million, respectively, at March 31, 2021 and $33 million and $268 million, respectively, at December 31, 2020 related to floating-to-fixed energy swap contracts with unaffiliated suppliers.

PHI, Pepco, DPL, and ACE

	As of March 31, 2021								As of December 31, 2020
PHI	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	527	$	—	$	—	$	527	$	86	$	—	$	—	$	86
Rabbi trust investments
Cash equivalents	53		—		—		53		55		—		—		55
Mutual funds	15		—		—		15		14		—		—		14
Fixed income	—		10		—		10		—		11		—		11
Life insurance contracts	—		26		35		61		—		26		34		60
Rabbi trust investments subtotal	68		36		35		139		69		37		34		140
Total assets	595		36		35		666		155		37		34		226
Liabilities
Deferred compensation obligation	—		(16)		—		(16)		—		(17)		—		(17)
Total liabilities	—		(16)		—		(16)		—		(17)		—		(17)
Total net assets	$	595	$	20	$	35	$	650	$	155	$	20	$	34	$	209

	Pepco								DPL								ACE
As of March 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)	$	128	$	—	$	—	$	128	$	50	$	—	$	—	$	50	$	349	$	—	$	—	$	349
Rabbi trust investments
Cash equivalents	53		—		—		53		—		—		—		—		—		—		—		—
Fixed income	—		2		—		2		—		—		—		—		—		—		—		—
Life insurance contracts	—		26		35		61		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	53		28		35		116		—		—		—		—		—		—		—		—
Total assets	181		28		35		244		50		—		—		50		349		—		—		349
Liabilities
Deferred compensation obligation	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total liabilities	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total net assets	$	181	$	26	$	35	$	242	$	50	$	—	$	—	$	50	$	349	$	—	$	—	$	349

	Pepco								DPL								ACE
As of December 31, 2020	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)	$	35	$	—	$	—	$	35	$	—	$	—	$	—	$	—	$	13	$	—	$	—	$	13
Rabbi trust investments
Cash equivalents	53		—		—		53		—		—		—		—		—		—		—		—
Fixed income	—		2		—		2		—		—		—		—		—		—		—		—
Life insurance contracts	—		26		34		60		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	53		28		34		115		—		—		—		—		—		—		—		—
Total assets	88		28		34		150		—		—		—		—		13		—		—		13
Liabilities
Deferred compensation obligation	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total liabilities	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total net assets	$	88	$	26	$	34	$	148	$	—	$	—	$	—	$	—	$	13	$	—	$	—	$	13

__________

(a)PHI excludes cash of $72 million and $74 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $5 million and none at March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $9 million and $10 million at March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. Pepco excludes cash of $34 million and $30 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $5 million and none at March 31, 2021 and December 31, 2020, respectively. DPL excludes cash of $14 million and $15 million at March 31, 2021 and December 31, 2020, respectively. ACE excludes cash of $17 million at both March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $9 million and $10 million at March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets.

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 months ended March 31, 2021 and 2020:

	Exelon		Generation							ComEd			PHI and Pepco
Three months ended March 31, 2021	Total		NDT Fund Investments		Mark-to-Market Derivatives			Total Generation		Mark-to-Market Derivatives			Life Insurance Contracts		Eliminated in Consolidation
Balance as of December 31, 2020	$	660	$	497	$	430		$	927	$	(301)		$	34	$	—
Total realized / unrealized gains (losses)
Included in net income	(276)		1		(278)		(a)	(277)		—			1		—
Included in noncurrent payables to affiliates	—		1		—			1		—			—		(1)
Included in regulatory assets	7		—		—			—		6		(b)	—		1
Change in collateral	(57)		—		(57)			(57)		—			—		—
Purchases, sales, issuances and settlements
Purchases	109		—		109			109		—			—		—
Sales	1		—		1			1		—			—		—
Settlements	(20)		(20)		—			(20)		—			—		—
Transfers out of Level 3	2		—		2		(c)	2		—			—		—
Balance as of March 31, 2021	$	426	$	479	$	207		$	686	$	(295)		$	35	$	—
The amount of total (losses) gains included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of March 31, 2021	$	(147)	$	1	$	(149)		$	(148)	$	—		$	1	$	—

	Exelon		Generation							ComEd			PHI and Pepco
Three Months Ended March 31, 2020	Total		NDT Fund Investments		Mark-to-Market Derivatives			Total Generation		Mark-to-Market Derivatives			Life Insurance Contracts		Eliminated in Consolidation
Balance as of December 31, 2019	$	1,068	$	511	$	817		$	1,328	$	(301)		$	41	$	—
Total realized / unrealized gains (losses)
Included in net income	10		(1)		10		(a)	9		—			1		—
Included in noncurrent payables to affiliates	—		(1)		—			(1)		—			—		1
Included in regulatory assets	(14)		—		—			—		(13)		(b)	—		(1)
Change in collateral	1		—		1			1		—			—		—
Purchases, sales, issuances and settlements
Purchases	42		3		39			42		—			—		—
Sales	(22)		—		(22)			(22)		—			—		—
Settlements	(14)		(14)		—			(14)		—			—		—
Transfers into Level 3	2		—		2		(c)	2		—			—		—
Transfers out of Level 3	15		—		15		(c)	15		—			—		—
Balance as of March 31, 2020	$	1,088	$	498	$	862		$	1,360	$	(314)		$	42	$	—
The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of March 31, 2020	$	187	$	(1)	$	187		$	186	$	—		$	1	$	—

__________

(a)Includes a reduction for the reclassification of $129 million and $177 million of realized losses due to the settlement of derivative contracts for the three months ended March 31, 2021 and 2020 respectively.

(b)Includes $2 million of decreases in fair value and an increase for realized losses due to settlements of $8 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended March 31, 2021. Includes $23 million of decrease in fair value and an increase for realized losses due to settlements of $10 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended March 31, 2020.

(c)Transfers into and out of Level 3 generally occur when the contract tenor becomes less and more observable respectively, primarily due to changes in market liquidity or assumptions for certain commodity contracts.

The following tables present the income statement classification of the total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis during the three months ended March 31, 2021 and 2020:

	Exelon								Generation						PHI and Pepco
	Operating Revenues		Purchased Power and Fuel		Operating and Maintenance		Other, net		Operating Revenues		Purchased Power and Fuel		Other, net		Operating and Maintenance
Total (losses) gains for the three months ended March 31, 2021	$	(116)	$	(162)	$	1	$	1	$	(116)	$	(162)	$	1	$	1
Total unrealized (losses) gains for the three months ended March 31, 2021	(65)		(84)		1		1		(65)		(84)		1		1

	Exelon								Generation						PHI and Pepco
	Operating Revenues		Purchased Power and Fuel		Operating and Maintenance		Other, net		Operating Revenues		Purchased Power and Fuel		Other, net		Operating and Maintenance
Total gains (losses) for the three months ended March 31, 2020	$	72	$	(62)	$	1	$	(1)	$	72	$	(62)	$	(1)	$	1
Total unrealized gains (losses) gains for the three months ended March 31, 2020	205		(18)		1		(1)		205		(18)		(1)		1

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 18 — Fair Value of Financial Assets and Liabilities of the Exelon 2020 Form 10-K.

Valuation Techniques Used to Determine Net asset Value (Exelon and Generation)

Certain NDT Fund Investments are not classified within the fair value hierarchy and are included under the heading “Not subject to leveling” in the table above. These investments are measured at fair value using NAV per share as a practical expedient and include commingled funds, mutual funds which are not publicly quoted, managed private credit funds, private equity and real estate funds.

For commingled funds and mutual funds, which are not publicly quoted, the fair value is primarily derived from the quoted prices in active markets on the underlying securities and can typically be redeemed monthly with 30 or less days of notice and without further restrictions. For managed private credit funds, the fair value is determined using a combination of valuation models including cost models, market models, and income models and typically cannot be redeemed until maturity of the term loan. Private equity and real estate investments include those in limited partnerships that invest in operating companies and real estate holding companies that are not publicly traded on a stock exchange, such as, leveraged buyouts, growth capital, venture capital, distressed investments, investments in natural resources, and direct investments in pools of real estate properties. These investments typically cannot be redeemed and are generally liquidated over a period of 8 to 10 years from the initial investment date, which is based on Exelon’s understanding of the investment funds. Private equity and real estate valuations are reported by the fund manager and are based on the valuation of the underlying investments, which include inputs such as cost, operating results, discounted future cash flows, market based comparable data, and independent appraisals from sources with professional qualifications. These valuation inputs are unobservable.

Mark-to-Market Derivatives (Exelon, Generation and ComEd)

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

Type of trade	Fair Value at March 31, 2021		Fair Value at December 31, 2020		Valuation Technique	Unobservable Input	2021 Range & Arithmetic Average				2020 Range & Arithmetic Average
Mark-to-market derivatives — Economic Hedges (Exelon and Generation)(a)(b)	$	90	$	245	Discounted Cash Flow	Forward power price	$1.35	-	$235	$32	$2.25	-	$163	$30
						Forward gas price	$1.42	-	$8.18	$2.59	$1.57	-	$7.88	$2.59
					Option Model	Volatility percentage	11%	-	116%	27%	11%	-	237%	32%
Mark-to-market derivatives — Proprietary trading (Exelon and Generation)(a)(b)	$	12	$	23	Discounted Cash Flow	Forward power price	$9	-	$102	$30	$10	-	$106	$27
Mark-to-market derivatives (Exelon and ComEd)	$	(295)	$	(301)	Discounted Cash Flow	Forward heat rate(c)	8x	-	9x	8.85x	8x	-	9x	8.85x
						Marketability reserve	3%	-	8%	4.93%	3%	-	8%	4.93%
						Renewable factor	90%	-	123%	99%	91%	-	123%	99%

__________

(a)The valuation techniques, unobservable inputs, ranges and arithmetic averages are the same for the asset and liability positions.

(b)The fair values do not include cash collateral posted on level three positions of $105 million and $162 million as of March 31, 2021 and December 31, 2020, respectively.

(c)Quoted forward natural gas rates are utilized to project the forward power curve for the delivery of energy at specified future dates. The natural gas curve is extrapolated beyond its observable period to the end of the contract’s delivery.

The inputs listed above, which are as of the balance sheet date, would have a direct impact on the fair values of the above instruments if they were adjusted. The significant unobservable inputs used in the fair value measurement of Generation’s commodity derivatives are forward commodity prices and for options is price volatility. Increases (decreases) in the forward commodity price in isolation would result in significantly higher (lower) fair values for long positions (contracts that give Generation the obligation or option to purchase a commodity), with offsetting impacts to short positions (contracts that give Generation the obligation or right to sell a commodity). Increases (decreases) in volatility would increase (decrease) the value for the holder of the option (writer of the option). Generally, a change in the estimate of forward commodity prices is unrelated to a change in the estimate of volatility of prices. An increase to the reserves listed above would decrease the fair value of the positions. An increase to the heat rate or renewable factors would increase the fair value accordingly. Generally, interrelationships exist between market prices of natural gas and power. As such, an increase in natural gas pricing would potentially have a similar impact on forward power markets.

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Commitments and Contingencies (All Registrants)

3 Months Ended

Mar. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies (All Registrants)

Commitments and Contingencies (All Registrants)

The following is an update to the current status of commitments and contingencies set forth in Note 19 of the Exelon 2020 Form 10-K.

Commitments

PHI Merger Commitments (Exelon, PHI, Pepco, DPL and ACE). Approval of the PHI Merger in Delaware, New Jersey, Maryland and the District of Columbia was conditioned upon Exelon and PHI agreeing to certain commitments. The following amounts represent total commitment costs that have been recorded since the acquisition date and the total remaining obligations for Exelon, PHI, Pepco, DPL, and ACE as of March 31, 2021:

Description	Exelon		PHI		Pepco		DPL		ACE
Total commitments	$	513	$	320	$	120	$	89	$	111
Remaining commitments(a)	79		64		53		7		4

__________

(a)Remaining commitments extend through 2026 and include rate credits, energy efficiency programs and delivery system modernization.

In addition, Exelon is committed to develop or to assist in the commercial development of approximately 37 MWs of new solar generation in Maryland, District of Columbia, and Delaware at an estimated cost of approximately $135 million, which will generate future earnings at Exelon and Generation. Investment costs, which are expected to be primarily capital in nature, are recognized as incurred and recorded in Exelon's and Generation's financial statements. As of March 31, 2021, 27 MWs of new generation were developed and Exelon and Generation have incurred costs of $121 million. Exelon has also committed to purchase 100 MWs of wind energy in PJM. DPL has committed to conducting three RFPs to procure up to a total of 120 MWs of wind RECs for the purpose of meeting Delaware's renewable portfolio standards. DPL has conducted two of the three wind REC RFPs. The first 40 MW wind REC tranche was conducted in 2017 and did not result in a purchase agreement. The second 40 MW wind REC tranche was conducted in 2018 and resulted in a proposed REC purchase agreement that was approved by the DPSC in 2019. The third and final 40 MW wind REC tranche will be conducted in 2022.

Commercial Commitments (All Registrants). The Registrants’ commercial commitments as of March 31, 2021, representing commitments potentially triggered by future events were as follows:

			Expiration within
	Total		2021		2022		2023		2024		2025		2026 and beyond
Exelon
Letters of credit	$	1,639	$	1,156	$	483	$	—	$	—	$	—	$	—
Surety bonds(a)	1,077		919		158		—		—		—		—
Financing trust guarantees	378		—		—		—		—		—		378
Guaranteed lease residual values(b)	29		—		3		4		6		5		11
Total commercial commitments	$	3,123	$	2,075	$	644	$	4	$	6	$	5	$	389
Generation
Letters of credit	$	1,623	$	1,141	$	482	$	—	$	—	$	—	$	—
Surety bonds(a)	932		794		138		—		—		—		—
Total commercial commitments	$	2,555	$	1,935	$	620	$	—	$	—	$	—	$	—
ComEd
Letters of credit	$	7	$	7	$	—	$	—	$	—	$	—	$	—
Surety bonds(a)	17		14		3		—		—		—		—
Financing trust guarantees	200		—		—		—		—		—		200
Total commercial commitments	$	224	$	21	$	3	$	—	$	—	$	—	$	200
PECO
Surety bonds(a)	$	2	$	2	$	—	$	—	$	—	$	—	$	—
Financing trust guarantees	178		—		—		—		—		—		178
Total commercial commitments	$	180	$	2	$	—	$	—	$	—	$	—	$	178
BGE
Letters of credit	$	3	$	2	$	1	$	—	$	—	$	—	$	—
Surety bonds(a)	3		3		—		—		—		—		—
Total commercial commitments	$	6	$	5	$	1	$	—	$	—	$	—	$	—
PHI
Surety bonds(a)	$	23	$	20	$	3	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	29		—		3		4		6		5		11
Total commercial commitments	$	52	$	20	$	6	$	4	$	6	$	5	$	11
Pepco
Surety bonds(a)	$	14	$	14	$	—	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	10		—		1		1		2		2		4
Total commercial commitments	$	24	$	14	$	1	$	1	$	2	$	2	$	4
DPL
Surety bonds(a)	$	5	$	2	$	3	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	12		—		1		2		3		2		4
Total commercial commitments	$	17	$	2	$	4	$	2	$	3	$	2	$	4
ACE
Surety bonds(a)	$	4	$	4	$	—	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	7		—		1		1		1		1		3
Total commercial commitments	$	11	$	4	$	1	$	1	$	1	$	1	$	3

__________

(a)Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds.

(b)Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The lease term associated with these assets ranges from 1 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $73 million guaranteed by Exelon and PHI, of which $25 million, $30 million, and $18 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 (Exelon and the Utility Registrants). ComEd, PECO, BGE, and DPL have identified sites where former MGP or gas purification activities have or may have resulted in actual site contamination. For almost all of these sites, there are additional PRPs that may share responsibility for the ultimate remediation of each location.

•ComEd has 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 2026.

•PECO has 8 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 settlements of natural gas distribution rate cases with the PAPUC, 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.

As of March 31, 2021 and December 31, 2020, the Registrants had accrued the following undiscounted amounts for environmental liabilities in Other current liabilities and Other deferred credits and other liabilities within their respective Consolidated Balance Sheets:

	March 31, 2021				December 31, 2020
	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	$	473	$	306	$	483	$	314
Generation	119		—		121		—
ComEd	281		280		293		293
PECO	23		21		23		21
BGE	6		5		2		—
PHI	44		—		44		—
Pepco	42		—		42		—
DPL	1		—		1		—
ACE	1		—		1		—

Cotter Corporation (Exelon and Generation). The EPA has advised Cotter Corporation (Cotter), a former ComEd subsidiary, that it is potentially liable in connection with radiological contamination at a site known as the West Lake Landfill in Missouri. In 2000, ComEd sold Cotter to an unaffiliated third-party. As part of the sale, ComEd agreed to indemnify Cotter for any liability arising in connection with the West Lake Landfill. In connection with Exelon’s 2001 corporate restructuring, this responsibility to indemnify Cotter was transferred to Generation. Including Cotter, there are three PRPs participating in the West Lake Landfill remediation proceeding. Investigation by Generation has identified a number of other parties who also may be PRPs and could be liable to contribute to the final remedy. Further investigation is ongoing.

In September 2018, the EPA issued its Record of Decision Amendment (RODA) for the selection of a final remedy. The RODA modified the remedy previously selected by EPA in its 2008 Record of Decision (ROD). While the ROD required only that the radiological materials and other wastes at the site be capped, the 2018 RODA requires partial excavation of the radiological materials in addition to the previously selected capping remedy. The RODA also allows for variation in depths of excavation depending on radiological concentrations. The EPA and the PRPs have entered into a Consent Agreement to perform the Remedial Design, which is expected to be completed by early 2022. In March 2019 the PRPs received Special Notice Letters from the EPA to perform the Remedial Action work. On October 8, 2019, Cotter (Generation’s indemnitee) provided a non-binding good faith offer to conduct, or finance, a portion of the remedy, subject to certain conditions. The total estimated cost of the remedy, taking into account the current EPA technical requirements and the total costs expected to be incurred collectively by the PRPs in fully executing the remedy, is approximately $280 million, including cost escalation on an undiscounted basis, which would be allocated among the final group of PRPs. Generation has determined that a loss associated with the EPA’s partial excavation and enhanced landfill cover remedy is probable and has recorded a liability included in the table above, that reflects management’s best estimate of Cotter’s allocable share of the ultimate cost. Given the joint and several nature of this liability, the magnitude of Generation’s ultimate liability will depend on the actual costs incurred to implement the required remedy as well as on the nature and terms of any cost-sharing arrangements with the final group of PRPs. Therefore, it is reasonably possible that the ultimate cost and Cotter's associated allocable share could differ significantly once these uncertainties are resolved, which could have a material impact on Exelon's and Generation's future financial statements.

One of the other PRPs has indicated it will be making a contribution claim against Cotter for costs that it has incurred to prevent a subsurface fire from spreading to those areas of the West Lake Landfill where radiological materials are believed to have been disposed. At this time, Exelon and Generation do not possess sufficient information to assess this claim and therefore are unable to estimate a range of loss, if any. As such, no liability has been recorded for the potential contribution claim. It is reasonably possible, however, that resolution of this matter could have a material, unfavorable impact on Exelon’s and Generation's financial statements.

In January 2018, the PRPs were advised by the EPA that it will begin an additional investigation and evaluation of groundwater conditions at the West Lake Landfill. In September 2018, the PRPs agreed to an Administrative Settlement Agreement and Order on Consent for the performance by the PRPs of the groundwater Remedial

Investigation and Feasibility Study (RI/FS). The purpose of this RI/FS is to define the nature and extent of any groundwater contamination from the West Lake Landfill site and evaluate remedial alternatives. Generation estimates the undiscounted cost for the groundwater RI/FS to be approximately $30 million. Generation determined a loss associated with the RI/FS is probable and has recorded a liability included in the table above that reflects management’s best estimate of Cotter’s allocable share of the cost among the PRPs. At this time Generation cannot predict the likelihood or the extent to which, if any, remediation activities may be required and therefore cannot estimate a reasonably possible range of loss for response costs beyond those associated with the RI/FS component. It is reasonably possible, however, that resolution of this matter could have a material, unfavorable impact on Exelon’s and Generation’s future financial statements.

In August 2011, Cotter was notified by the DOJ that Cotter is considered a PRP with respect to the government’s clean-up costs for contamination attributable to low level radioactive residues at a former storage and reprocessing facility named Latty Avenue near St. Louis, Missouri. The Latty Avenue site is included in ComEd’s (now Generation's) indemnification responsibilities discussed above as part of the sale of Cotter. The radioactive residues had been generated initially in connection with the processing of uranium ores as part of the U.S. Government’s Manhattan Project. Cotter purchased the residues in 1969 for initial processing at the Latty Avenue facility for the subsequent extraction of uranium and metals. In 1976, the NRC found that the Latty Avenue site had radiation levels exceeding NRC criteria for decontamination of land areas. Latty Avenue was investigated and remediated by the United States Army Corps of Engineers pursuant to funding under FUSRAP. Pursuant to a series of annual agreements since 2011, the DOJ and the PRPs have tolled the statute of limitations until August 31, 2021 so that settlement discussions can proceed. On August 3, 2020, the DOJ advised Cotter and the other PRPs that it is seeking approximately $90 million from all the PRPs and has directed that the PRPs must submit a good faith joint proposed settlement offer. At this time, the DOJ has stayed their request for a good faith offer while the parties review cost documentation associated with the cost claim. Generation has determined that a loss associated with this matter is probable under its indemnification agreement with Cotter and has recorded an estimated liability, which is included in the table above.

Benning Road Site (Exelon, Generation, 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 was formerly the location of a Pepco Energy Services electric generating facility, which 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 with the DOEE, which requires Pepco and Pepco Energy Services to conduct a RI/FS for the Benning Road site and an approximately 10 to 15-acre portion of the adjacent Anacostia River.

Since 2013, Pepco and Pepco Energy Services (now Generation, pursuant to Exelon's 2016 acquisition of PHI) have been performing RI work and have submitted multiple draft RI reports to the DOEE. In September 2019, Pepco and Generation issued a draft “final” RI report which DOEE approved on February 3, 2020. Pepco and Generation 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 March 16, 2022. After completion and approval of the FS, DOEE will prepare a Proposed Plan for public comment and then issue a ROD identifying any further response actions determined to be necessary. PHI, Pepco, and Generation 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 Pepco and Generation, DOEE and the National Park Service 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 Pepco and Pepco Energy Services as part of the Benning RI/FS, as well as similar sampling efforts conducted by owners of other sites adjacent to this segment of the river and supplemental river sampling conducted by DOEE’s contractor. In April 2018, DOEE released a draft RI report for public review and comment. Pepco submitted written comments to the draft RI and participated in a public hearing.

Pepco has determined that it is probable that costs for remediation will be incurred and recorded a liability in the third quarter 2019 for management’s best estimate of its share of those costs. On September 30, 2020, DOEE released its Interim ROD. The Interim ROD reflects an adaptive management approach which will require several

identified “hot spots” in the river to be addressed first while continuing to conduct studies and to monitor the river to evaluate improvements and determine potential future remediation plans. The adaptive management process chosen by DOEE is less intrusive, provides more long-term 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. 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 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 range of loss.

Litigation and Regulatory Matters

Asbestos Personal Injury Claims (Exelon and Generation). Generation maintains a reserve for claims associated with asbestos-related personal injury actions in certain facilities that are currently owned by Generation or were previously owned by ComEd and PECO. The estimated liabilities are recorded on an undiscounted basis and exclude the estimated legal costs associated with handling these matters, which could be material.

At March 31, 2021 and December 31, 2020, Exelon and Generation had recorded estimated liabilities of approximately $88 million and $89 million, respectively, in total for asbestos-related bodily injury claims. As of March 31, 2021, approximately $24 million of this amount related to 243 open claims presented to Generation, while the remaining $64 million is for estimated future asbestos-related bodily injury claims anticipated to arise through 2055, based on actuarial assumptions and analyses, which are updated on an annual basis. On a quarterly basis, Generation monitors actual experience against the number of forecasted claims to be received and expected claim payments and evaluates whether adjustments to the estimated liabilities are necessary.

It is reasonably possible that additional exposure to estimated future asbestos-related bodily injury claims in excess of the amount accrued could have a material, unfavorable impact on Exelon’s and Generation’s financial statements. However, management cannot reasonably estimate a range of loss beyond the amounts recorded.

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 a party to the DPA, and therefore the investigation by the USAO into Exelon’s activities ended with no charges being brought against Exelon. The SEC’s investigation remains ongoing and Exelon and ComEd have cooperated fully and intend to continue to cooperate fully with the SEC. Exelon and ComEd cannot predict the outcome of the SEC investigation. No loss contingency has been reflected in Exelon's and ComEd's consolidated financial statements with respect to the SEC investigation, as this contingency is neither probable nor reasonably estimable at this time.

Subsequent to Exelon announcing the receipt of the subpoenas, various lawsuits were filed, and various demand letters were received related to the subject of the subpoenas, the conduct described in the DPA and the SEC's investigation, including:

•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. Defendants' responsive pleading is due June 9, 2021.

•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. These three state cases were consolidated into a single action in October of 2020. In addition, on November 2, 2020, the Citizens Utility Board (CUB) filed a motion to intervene in the state 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, to jointly engage in mediation and have informed the court. The parties will report back to the court on the status of the mediation planning on April 29, 2021. A tentative date of June 1, 2021 has been set for oral argument on the pending motion to dismiss, but the parties have agreed to extend that date so long as a date to mediate has been selected by that time.

•Four putative class action lawsuits against ComEd and Exelon were filed in federal court in the third quarter of 2020 alleging, among other things, civil violations of federal racketeering laws. In addition, CUB filed a motion to intervene in these cases on October 22, 2020 which was granted on December 23, 2020. In addition, on December 2, 2020, the court appointed interim lead plaintiffs in the federal cases which consisted of counsel for three of the four federal cases. These plaintiffs filed a consolidated complaint on January 5, 2021. CUB also filed its own complaint against ComEd only on the same day. The remaining federal case, Potter, et al. v. Exelon et al, differed from the other lawsuits as it named additional individual defendants not named in the consolidated complaint. The Potter plaintiffs decided not to move forward with their separate lawsuit at this time and 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. Briefing on that motion was completed on March 22, 2021. As noted above, on March 25, 2021, the parties agreed, along with the state court plaintiffs, to jointly engage in mediation. The parties have notified the court of their decision to mediate. Oral argument on the pending motion to dismiss and any discovery will be stayed pending mediation.

•Five shareholders sent letters to the Exelon Board of Directors between 2020 and 2021 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.

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.

Impacts of the February 2021 Extreme Cold Weather Event and Texas-based Generating Assets Outages (Exelon and Generation). Beginning on February 15, 2021, Generation’s Texas-based generating assets within the ERCOT market, specifically Colorado Bend II, Wolf Hollow II, and Handley, experienced outages as a result of extreme cold weather conditions. In addition, those weather conditions drove increased demand for service, dramatically increased wholesale power prices, and also increased gas prices in certain regions. See Note 3 — Regulatory Matters for additional information.

Various lawsuits have been filed against Generation during March and April of 2021 related to these events, including:

•On March 5, 2021, Generation, along with more than 160 power generators and transmission and distribution companies, was sued by approximately 160 individually named plaintiffs, purportedly on behalf of all Texans who allegedly suffered loss of life or sustained personal injury, property damage or other losses as a result of the weather events. The plaintiffs allege that the defendants failed to properly prepare for the cold weather and failed to properly conduct their operations, seeking compensatory as well as punitive damages. On April 26, 2021, another multi-plaintiff lawsuit was filed on behalf of approximately 90 plaintiffs against more than 300 defendants, including Generation, involving similar allegations of liability and claims of personal injury and property damage. During March and April of 2021, approximately 45 additional wrongful death lawsuits, naming multiple defendants including Generation, were filed by individual plaintiffs in different Texas counties, all arising out of the February weather events. Co-defendants in these lawsuits include ERCOT, transmission and distribution utilities and other generators. Generation disputes liability and denies that it is responsible for any of plaintiffs’ alleged claims and is vigorously contesting them. No loss contingencies have been reflected in Exelon’s and Generation’s consolidated financial statements with respect to these matters, as such contingencies are neither probable nor reasonably estimable at this time.

•On March 22, 2021, a LDC filed a lawsuit in Missouri federal court against Generation for breach of contract and unjust enrichment, seeking damages of approximately $40 million. The plaintiff claims that Generation failed to deliver gas to its customers in February of 2021, causing the plaintiff to incur damages by forcing it to purchase gas for Generation’s customers and by Generation’s refusal to pay the resulting penalties. On March 26, 2021, Generation filed a complaint with the MPSC against the LDC to void the OFO penalties, or alternatively to grant a waiver or variance from the tariff requirements, to prohibit the LDC from billing or otherwise attempting to collect from Generation or any Missouri customer any portion of the penalties claimed by the LDC until the resolution of the complaint, and to prohibit the LDC from taking any retaliatory measure, including termination of service. Generation has requested expedited treatment, but there is no timeline by which the MPSC must act. Based on the penalty provisions within the tariff that was in effect at the relevant time, Exelon and Generation recorded a liability of approximately $40 million as of March 31, 2021.

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.

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Changes in Accumulated Other Comprehensive Income (Exelon)

3 Months Ended

Mar. 31, 2021

Changes in Accumulated Other Comprehensive Income [Abstract]

Changes in Accumulated Other Comprehensive Income [Text Block]

Changes in Accumulated Other Comprehensive Income (Exelon)

The following tables present changes in Exelon's AOCI, net of tax, by component:

Three Months Ended March 31, 2021	Losses on Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items (a)		Foreign Currency Items		Total
Beginning balance	$	(5)	$	(3,372)	$	(23)	$	(3,400)
OCI before reclassifications	—		(2)		1		(1)
Amounts reclassified from AOCI	—		55		—		55
Net current-period OCI	—		53		1		54
Ending balance	$	(5)	$	(3,319)	$	(22)	$	(3,346)

Three Months Ended March 31, 2020	Losses on Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items (a)		Foreign Currency Items		Total
Beginning balance	$	(2)	$	(3,165)	$	(27)	$	(3,194)
OCI before reclassifications	(1)		(7)		(8)		(16)
Amounts reclassified from AOCI	—		37		—		37
Net current-period OCI	(1)		30		(8)		21
Ending balance	$	(3)	$	(3,135)	$	(35)	$	(3,173)

_________

(a)AOCI amounts are included in the computation of net periodic pension and OPEB cost. See Note 10 — Retirement Benefits for additional information. See Exelon's Statements of Operations and Comprehensive Income for individual components of AOCI.

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

	Three Months Ended March 31,
	2021		2020
Pension and non-pension postretirement benefit plans:
Prior service benefit reclassified to periodic benefit cost	$	1	$	4
Actuarial loss reclassified to periodic benefit cost	(19)		(17)
Pension and non-pension postretirement benefit plans valuation adjustment	—		3

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Variable Interest Entities (Exelon, Generation, PHI and ACE)

3 Months Ended

Mar. 31, 2021

Variable Interest Entity [Abstract]

Variable Interest Entity Disclosure

Variable Interest Entities (Exelon, Generation, PHI and ACE)

At March 31, 2021 and December 31, 2020, Exelon, Generation, PHI, and ACE collectively consolidated several VIEs or VIE groups for which the applicable Registrant was the primary beneficiary (see Consolidated VIEs below) and had significant interests in several other VIEs for which the applicable Registrant does not have the power to direct the entities’ activities and, accordingly, was not the primary beneficiary (see Unconsolidated VIEs below). Consolidated and unconsolidated VIEs are aggregated to the extent that the entities have similar risk profiles.

Consolidated VIEs

The table below shows the carrying amounts and classification of the consolidated VIEs’ assets and liabilities included in the consolidated financial statements of Exelon, Generation, PHI, and ACE as of March 31, 2021 and December 31, 2020. The assets, except as noted in the footnotes to the table below, can only be used to settle obligations of the VIEs. The liabilities, except as noted in the footnote to the table below, are such that creditors, or beneficiaries, do not have recourse to the general credit of Exelon, Generation, PHI, and ACE.

	March 31, 2021								December 31, 2020
	Exelon		Generation		PHI (a)		ACE		Exelon		Generation		PHI (a)		ACE
Cash and cash equivalents	$	175	$	175	$	—	$	—	$	98	$	98	$	—	$	—
Restricted cash and cash equivalents	37		33		4		4		47		44		3		3
Accounts receivable
Customer	145		145		—		—		148		148		—		—
Other	35		35		—		—		36		36		—		—
Unamortized energy contract assets	22		22		—		—		22		22		—		—
Inventories, net
Materials and supplies	242		242		—		—		244		244		—		—
Assets held for sale(b)	—		—		—		—		101		101		—		—
Other current assets	448		443		5		—		674		669		5		—
Total current assets	1,104		1,095		9		4		1,370		1,362		8		3
Property, plant, and equipment, net	5,747		5,747		—		—		5,803		5,803		—		—
Nuclear decommissioning trust funds	3,089		3,089		—		—		3,007		3,007		—		—
Unamortized energy contract assets	243		243		—		—		249		249		—		—
Other noncurrent assets	47		38		9		9		52		42		10		10
Total noncurrent assets	9,126		9,117		9		9		9,111		9,101		10		10
Total assets(c)	$	10,230	$	10,212	$	18	$	13	$	10,481	$	10,463	$	18	$	13
Long-term debt due within one year	$	90	$	69	$	21	$	16	$	94	$	68	$	26	$	21
Accounts payable	95		95		—		—		81		81		—		—
Accrued expenses	67		67		—		—		70		70		—		—
Unamortized energy contract liabilities	3		3		—		—		4		4		—		—
Liabilities held for sale(b)	—		—		—		—		16		16		—		—
Other current liabilities	1		1		—		—		5		5		—		—
Total current liabilities	256		235		21		16		270		244		26		21
Long-term debt	861		861		—		—		889		889		—		—
Asset retirement obligations	2,347		2,347		—		—		2,318		2,318		—		—
Other noncurrent liabilities	116		116		—		—		129		129		—		—
Total noncurrent liabilities	3,324		3,324		—		—		3,336		3,336		—		—
Total liabilities(d)	$	3,580	$	3,559	$	21	$	16	$	3,606	$	3,580	$	26	$	21

_________

(a)Includes certain purchase accounting adjustments from the PHI merger not pushed down to ACE.

(b)In the fourth quarter of 2020, Generation entered into an agreement for the sale of a significant portion of Generation's solar business, and as a result of this transaction, Exelon and Generation reclassified the consolidated VIEs' solar assets and liabilities as held for sale. Completion of the transaction occurred in the first quarter of 2021. Refer to Note 2 - Mergers, Acquisitions, and Dispositions for additional information on the solar business.

(c)Exelon’s and Generation’s balances include unrestricted assets for current unamortized energy contract assets of $22 million and $22 million, non-current unamortized energy contract assets of $222 million and $249 million, Assets held for sale of $0 million and $9 million, and other unrestricted assets of $1 million and $1 million as of March 31, 2021 and December 31, 2020, respectively

(d)Exelon’s and Generation’s balances include liabilities with recourse of $2 million and $8 million as of March 31, 2021 and December 31, 2020, respectively.

As of March 31, 2021 and December 31, 2020, Exelon's and Generation's consolidated VIEs consist of:

Consolidated VIE or VIE groups:	Reason entity is a VIE:	Reason Generation is primary beneficiary:
CENG - A joint venture between Generation and EDF. Generation has a 50.01% equity ownership in CENG. See additional discussion below.	Disproportionate relationship between equity interest and operational control as a result of the NOSA described further below.	Generation conducts the operational activities.
EGRP - A collection of wind and solar project entities. Generation has a 51% equity ownership in EGRP. See additional discussion below.	Similar structure to a limited partnership and the limited partners do not have kick out rights with respect to the general partner.	Generation conducts the operational activities.
Bluestem Wind Energy Holdings, LLC - A Tax Equity structure which is consolidated by EGRP. Generation has a noncontrolling interest.	Similar structure to a limited partnership and the limited partners do not have kick out rights with respect to the general partner.	Generation conducts the operational activities.
Antelope Valley - A solar generating facility, which is 100% owned by Generation. Antelope Valley sells all of its output to PG&E through a PPA.	The PPA contract absorbs variability through a performance guarantee.	Generation conducts all activities.
Equity investment in distributed energy company - Generation has a 31% equity ownership. This distributed energy company has an interest in an unconsolidated VIE. (See Unconsolidated VIEs disclosure below). Generation fully impaired this investment in 2019.	Similar structure to a limited partnership and the limited partners do not have kick out rights with respect to the general partner.	Generation conducts the operational activities.
NER - A bankruptcy remote, special purpose entity which is 100% owned by Generation, which purchases certain of Generation’s customer accounts receivable arising from the sale of retail electricity. NER’s assets will be available first and foremost to satisfy the claims of the creditors of NER. See Note 6 - Accounts Receivable for additional information on the sale of receivables.	Equity capitalization is insufficient to support its operations.	Generation conducts all activities.

CENG - On April 1, 2014, Generation, CENG, and subsidiaries of CENG executed the NOSA pursuant to which Generation conducts all activities associated with the operations of the CENG fleet and provides corporate and administrative services to CENG and the CENG fleet for the remaining life of the CENG nuclear plants as if they were a part of the Generation nuclear fleet, subject to the CENG member rights of EDF.

EDF has the option to sell its 49.99% equity interest in CENG to Generation. On November 20, 2019, Generation received notice of EDF's intention to exercise the put option to sell its interest in CENG to Generation and the put automatically exercised on January 19, 2020. Refer to Note 2 - Mergers, Acquisitions, and Dispositions for additional information.

Exelon and Generation, where indicated, provide the following support to CENG:

•Generation executed an Indemnity Agreement pursuant to which Generation agreed to indemnify EDF against third-party claims that may arise from any future nuclear incident (as defined in the Price-Anderson Act) in connection with the CENG nuclear plants or their operations. Exelon guarantees Generation’s obligations under this Indemnity Agreement. See Note 19 — Commitments and Contingencies of the Exelon 2020 Form 10-K for more details,

•Generation and EDF share in the $688 million of contingent payment obligations for the payment of contingent retrospective premium adjustments for the nuclear liability insurance, and

•Exelon has executed an agreement to provide up to $245 million to support the operations of CENG as well as a $165 million guarantee of CENG’s cash pooling agreement with its subsidiaries.

EGRP - EGRP is a collection of wind and solar project entities and some of these project entities are VIEs that are consolidated by EGRP. Generation owns a number of limited liability companies that build, own, and operate solar and wind power facilities some of which are owned by EGRP. While Generation or EGRP owns 100% of the solar entities and 100% of the majority of the wind entities, it has been determined that certain of the solar and

wind entities are VIEs because the entities require additional subordinated financial support in the form of a parental guarantee of debt, loans from the customers in order to obtain the necessary funds for construction of the solar facilities, or the customers absorb price variability from the entities through the fixed price power and/or REC purchase agreements. Generation is the primary beneficiary of these solar and wind entities that qualify as VIEs because Generation controls the design, construction, and operation of the facilities. There is limited recourse to Generation related to certain solar and wind entities.

In 2017, Generation’s interests in EGRP were contributed to and are pledged for the ExGen Renewables IV non-recourse debt project financing structure. Refer to Note 17 — Debt and Credit Agreements of the Exelon 2020 Form 10-K for additional information on ExGen Renewables IV.

As of March 31, 2021 and December 31, 2020, Exelon's, PHI's and ACE's consolidated VIE consists of:

Consolidated VIEs:	Reason entity is a VIE:	Reason ACE is the primary beneficiary:
ACE Funding - A special purpose entity formed by ACE for the purpose of securitizing authorized portions of ACE’s recoverable stranded costs through the issuance and sale of Transition Bonds. Proceeds from the sale of each series of Transition Bonds by ATF were transferred to ACE in exchange for the transfer by ACE to ATF of the right to collect a non-bypassable Transition Bond Charge from ACE customers pursuant to bondable stranded costs rate orders issued by the NJBPU in an amount sufficient to fund the principal and interest payments on Transition Bonds and related taxes, expenses and fees.	ACE’s equity investment is a variable interest as, by design, it absorbs any initial variability of ATF. The bondholders also have a variable interest for the investment made to purchase the Transition Bonds.	ACE controls the servicing activities.

Unconsolidated VIEs

Exelon’s and Generation’s variable interests in unconsolidated VIEs generally include equity investments and energy purchase and sale contracts. For the equity investments, the carrying amount of the investments is reflected in Exelon’s and Generation’s Consolidated Balance Sheets in Investments. For the energy purchase and sale contracts (commercial agreements), the carrying amount of assets and liabilities in Exelon’s and Generation’s Consolidated Balance Sheets that relate to their involvement with the VIEs are predominately related to working capital accounts and generally represent the amounts owed by, or owed to, Exelon and Generation for the deliveries associated with the current billing cycles under the commercial agreements.

As of March 31, 2021 and December 31, 2020, Exelon and Generation had significant unconsolidated variable interests in several VIEs for which Exelon or Generation, as applicable, was not the primary beneficiary. These interests include certain equity method investments and certain commercial agreements.

The following table presents summary information about Exelon's and Generation’s significant unconsolidated VIE entities:

	March 31, 2021						December 31, 2020
	Commercial Agreement VIEs		Equity Investment VIEs		Total		Commercial Agreement VIEs		Equity Investment VIEs		Total
Total assets(a)	$	789	$	386	$	1,175	$	777	$	401	$	1,178
Total liabilities(a)	95		218		313		61		223		284
Exelon's ownership interest in VIE(a)	—		150		150		—		157		157
Other ownership interests in VIE(a)	694		18		712		716		21		737

_________

(a)These items represent amounts on the unconsolidated VIE balance sheets, not in Exelon’s or Generation’s Consolidated Balance Sheets. These items are included to provide information regarding the relative size of the unconsolidated VIEs. Exelon and Generation do not have any exposure to loss as they do not have a carrying amount in the equity investment VIEs as of March 31, 2021 and December 31, 2020.

As of March 31, 2021 and December 31, 2020, Exelon's and Generation's unconsolidated VIEs consist of:

Unconsolidated VIE groups:	Reason entity is a VIE:	Reason Generation is not the primary beneficiary:
Equity investments in distributed energy companies - 1) Generation has a 90% equity ownership in a distributed energy company. 2) Generation, via a consolidated VIE, has a 90% equity ownership in another distributed energy company (See Consolidated VIEs disclosure above). Generation fully impaired this investment in 2019.	Similar structures to a limited partnership and the limited partners do not have kick out rights with respect to the general partner.	Generation does not conduct the operational activities.
Energy Purchase and Sale agreements - Generation has several energy purchase and sale agreements with generating facilities.	PPA contracts that absorb variability through fixed pricing.	Generation does not conduct the operational activities.

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Supplemental Financial Information (All Registrants)

3 Months Ended

Mar. 31, 2021

Supplemental Financial Information [Abstract]

Supplemental Financial Information (All Registrants)

Supplemental Financial Information (All Registrants)

Supplemental Statement of Operations Information

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

	Operating revenues
	Exelon		Generation		PHI		DPL
Three Months Ended March 31, 2021
Operating lease income	$	4	$	3	$	1	$	1
Variable lease income	64		64		—		—
Three Months Ended March 31, 2020
Operating lease income	$	5	$	3	$	1	$	1
Variable lease income	69		69		—		—

	Taxes other than income taxes
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Utility taxes(a)	$	217	$	24	$	59	$	35	$	25	$	74	$	67	$	6	$	1
Property	154		68		8		4		42		32		21		10		1
Payroll	61		28		7		4		5		7		2		1		—
Three Months Ended March 31, 2020
Utility taxes(a)	$	218	$	26	$	60	$	31	$	26	$	75	$	69	$	6	$	—
Property	150		69		7		4		39		31		21		9		1
Payroll	63		31		7		4		4		8		2		1		1

__________

(a)Generation’s utility tax represents gross receipts tax related to its retail operations, and the Utility Registrants' utility taxes represents 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		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Decommissioning-related activities:
Net realized income on NDT funds(a)
Regulatory Agreement Units	$	291	$	291	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Non-Regulatory Agreement Units	203		203		—		—		—		—		—		—		—
Net unrealized gains on NDT funds
Regulatory Agreement Units	(82)		(82)		—		—		—		—		—		—		—
Non-Regulatory Agreement Units	(66)		(66)		—		—		—		—		—		—		—
Regulatory offset to NDT fund-related activities(b)	(167)		(167)		—		—		—		—		—		—		—
Decommissioning-related activities	179		179		—		—		—		—		—		—		—
AFUDC — Equity	28		—		4		6		7		11		9		1		1
Non-service net periodic benefit cost	20		—		—		—		—		—		—		—		—
Three Months Ended March 31, 2020
Decommissioning-related activities:
Net realized income on NDT funds(a)
Regulatory Agreement Units	$	47	$	47	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Non-Regulatory Agreement Units	82		82		—		—		—		—		—		—		—
Net unrealized gains on NDT funds
Regulatory Agreement Units	(932)		(932)		—		—		—		—		—		—		—
Non-Regulatory Agreement Units	(706)		(706)		—		—		—		—		—		—		—
Regulatory offset to NDT fund-related activities(b)	709		709		—		—		—		—		—		—		—
Decommissioning-related activities	(800)		(800)		—		—		—		—		—		—		—
AFUDC — Equity	23		—		6		3		5		9		6		1		2
Non-service net periodic benefit cost	10		—		—		—		—		—		—		—		—

__________

(a)Realized income includes interest, dividends and realized gains and losses on sales of NDT fund investments.

(b)Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of income taxes related to all NDT fund activity for those units. See Note 10 — Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information regarding the accounting for nuclear decommissioning.

Supplemental Cash Flow Information

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

	Depreciation, amortization and accretion
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Property, plant, and equipment(a)	$	1,522	$	928	$	239	$	82	$	106	$	154	$	67	$	42	$	37
Amortization of regulatory assets(a)	160		—		53		4		46		56		35		11		10
Amortization of intangible assets, net(a)	15		12		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(b)	4		3		—		—		—		—		—		—		—
Nuclear fuel(c)	276		276		—		—		—		—		—		—		—
ARO accretion(d)	127		127		—		—		—		—		—		—		—
Total depreciation, amortization and accretion	$	2,104	$	1,346	$	292	$	86	$	152	$	210	$	102	$	53	$	47
Three Months Ended March 31, 2020
Property, plant, and equipment(a)	$	856	$	290	$	228	$	79	$	97	$	144	$	64	$	38	$	34
Amortization of regulatory assets(a)	149		—		45		7		46		50		31		10		9
Amortization of intangible assets, net(a)	16		14		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(b)	2		2		—		—		—		—		—		—		—
Nuclear fuel(c)	231		231		—		—		—		—		—		—		—
ARO accretion(d)	124		124		—		—		—		—		—		—		—
Total depreciation, amortization and accretion	$	1,378	$	661	$	273	$	86	$	143	$	194	$	95	$	48	$	43

__________

(a)Included in Depreciation and amortization in the Registrants' Consolidated Statements of Operations and Comprehensive Income.

(b)Included in Operating revenues or Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

(c)Included in Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

(d)Included in Operating and maintenance expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

	Other non-cash operating activities
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Pension and non-pension postretirement benefit costs	$	95	$	26	$	32	$	2	$	14	$	12	$	2	$	1	$	3
Allowance for credit losses	85		34		13		24		4		10		5		4		1
Other decommissioning-related activity(a)	(322)		(332)		—		—		—		—		—		—		—
Energy-related options(b)	17		17		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(c)	(129)		—		(54)		(10)		(18)		(46)		(26)		(9)		(11)
Long-term incentive plan	32		—		—		—		—		—		—		—		—
Amortization of operating ROU asset	37		21		—		—		7		7		1		3		1
AFUDC - Equity	(28)		—		(4)		(6)		(7)		(11)		(9)		(1)		(1)
Three Months Ended March 31, 2020
Pension and non-pension postretirement benefit costs	$	98	$	27	$	28	$	1	$	15	$	17	$	3	$	1	$	3
Allowance for credit losses	45		4		7		17		7		10		4		3		3
Other decommissioning-related activity(a)	128		128		—		—		—		—		—		—		—
Energy-related options(b)	6		6		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(d)	(71)		—		(17)		—		(35)		(19)		(15)		(4)		—
Long-term incentive plan	(7)		—		—		—		—		—		—		—		—
Amortization of operating ROU asset	51		35		—		—		8		5		2		2		1
AFUDC - Equity	(23)		—		(6)		(3)		(5)		(9)		(6)		(1)		(2)

__________

(a)Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income, and income taxes related to all NDT fund activity for these units. See Note 10 — Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information regarding the accounting for nuclear decommissioning.

(b)Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations.

(c)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, and DPL, reflects the change in regulatory assets and liabilities associated with their decoupling mechanisms and transmission formula rates. For PECO and ACE, reflects the change in regulatory assets and liabilities associated with their transmission formula rates. See Note 3 — Regulatory Matters for additional information.

(d)For ComEd, reflects the true-up adjustments in regulatory assets and liabilities associated with its distribution and energy efficiency formula rates. For BGE, Pepco, and DPL, reflects the change in regulatory assets and liabilities associated with their decoupling mechanisms. See Note 3 — Regulatory Matters for additional information.

The following tables provide a reconciliation of cash, cash equivalents and restricted cash reported within the Registrants’ Consolidated Balance Sheets that sum to the total of the same amounts in their Consolidated Statements of Cash Flows.

	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2021
Cash and cash equivalents	$	1,908	$	721	$	86	$	48	$	21	$	558	$	134	$	64	$	353
Restricted cash and cash equivalents	374		41		270		7		1		37		33		—		4
Restricted cash included in other long-term assets	52		—		43		—		—		9		—		—		9
Total cash, restricted cash, and cash equivalents	$	2,334	$	762	$	399	$	55	$	22	$	604	$	167	$	64	$	366
December 31, 2020
Cash and cash equivalents	$	663	$	226	$	83	$	19	$	144	$	111	$	30	$	15	$	17
Restricted cash and cash equivalents	438		89		279		7		1		39		35		—		3
Restricted cash included in other long-term assets	53		—		43		—		—		10		—		—		10
Cash, restricted cash, and cash equivalents - Held for Sale	12		12		—		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents	$	1,166	$	327	$	405	$	26	$	145	$	160	$	65	$	15	$	30
March 31, 2020
Cash and cash equivalents	$	1,457	$	821	$	514	$	31	$	11	$	49	$	18	$	7	$	8
Restricted cash and cash equivalents	414		150		211		7		1		37		33		—		3
Restricted cash included in other long-term assets	121		—		108		—		—		12		—		—		12
Total cash, restricted cash, and cash equivalents	$	1,992	$	971	$	833	$	38	$	12	$	98	$	51	$	7	$	23
December 31, 2019
Cash and cash equivalents	$	587	$	303	$	90	$	21	$	24	$	131	$	30	$	13	$	12
Restricted cash and cash equivalents	358		146		150		6		1		36		33		—		2
Restricted cash included in other long-term assets	177		—		163		—		—		14		—		—		14
Total cash, restricted cash, and cash equivalents	$	1,122	$	449	$	403	$	27	$	25	$	181	$	63	$	13	$	28

For additional information on restricted cash see Note 1 — Significant Accounting Policies of the Exelon 2020 Form 10-K.

Supplemental Balance Sheet Information

The following tables provide additional information about material items recorded in the Registrants' Consolidated Balance Sheets.

	Accrued expenses
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2021
Compensation-related accruals(a)	$	581	$	210	$	91	$	42	$	49	$	73	$	26	$	15	$	12
Taxes accrued	540		279		70		18		50		108		92		10		12
Interest accrued	424		76		65		36		41		79		37		20		20
December 31, 2020
Compensation-related accruals(a)	$	1,069	$	426	$	170	$	73	$	84	$	109	$	36	$	18	$	17
Taxes accrued	527		229		94		16		73		117		90		18		12
Interest accrued	331		44		109		37		46		51		26		7		12

__________

(a)Primarily includes accrued payroll, bonuses and other incentives, vacation and benefits.

XML

Related Party Transactions (All Registrants)

3 Months Ended

Mar. 31, 2021

Related Party Transactions [Abstract]

Related Party Transactions (All Registrants)

Related Party Transactions (All Registrants)

Operating revenues from affiliates

Generation

The following table presents Generation’s Operating revenues from affiliates, which are primarily recorded as Purchased power from affiliates and an immaterial amount recorded as Operating and maintenance expense from affiliates at the Utility Registrants:

	Three Months Ended March 31,
	2021		2020
Operating revenues from affiliates:
ComEd(a)(b)	$	78	$	90
PECO(c)	42		37
BGE(d)	72		99
PHI	100		103
Pepco(e)	75		79
DPL(f)	21		22
ACE(g)	4		2
Other	3		1
Total operating revenues from affiliates (Generation)	$	295	$	330

__________

(a)Generation has an ICC-approved RFP contract with ComEd to provide a portion of ComEd’s electricity supply requirements. Generation also sells RECs and ZECs to ComEd.

(b)For the three months ended March 31, 2021, ComEd’s Purchased power from Generation of $84 million is recorded as Operating revenues from ComEd of $78 million and as Purchased power and fuel from ComEd of $6 million at Generation. For the three months ended March 31, 2020, ComEd’s Purchased power from Generation of $97 million is recorded as Operating revenues from ComEd of $90 million and as Purchased power and fuel from ComEd of $7 million at Generation.

(c)Generation provides electric supply to PECO under contracts executed through PECO’s competitive procurement process. In addition, Generation has a ten-year agreement with PECO to sell solar AECs.

(d)Generation provides a portion of BGE’s energy requirements under its MDPSC-approved market-based SOS and gas commodity programs.

(e)Generation provides electric supply to Pepco under contracts executed through Pepco's competitive procurement process approved by the MDPSC and DCPSC.

(f)Generation provides a portion of DPL's energy requirements under its MDPSC and DPSC-approved market-based SOS commodity programs.

(g)Generation provides electric supply to ACE under contracts executed through ACE's competitive procurement process.

PHI

PHI’s Operating revenues from affiliates are primarily with BSC for services that PHISCO provides to BSC.

Operating and maintenance expense from affiliates

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 March 31,				Three Months Ended March 31,
	2021		2020		2021		2020
Exelon
BSC					$	124	$	113
PHISCO					17		14
Generation
BSC	$	144	$	140	10		11
ComEd
BSC	71		72		45		42
PECO
BSC	39		37		17		16
BGE
BSC	43		41		20		28
PHI
BSC	39		37		32		16
PHISCO	—		—		17		14
Pepco
BSC	22		21		13		6
PHISCO	30		30		7		6
DPL
BSC	14		13		10		5
PHISCO	25		24		5		4
ACE
BSC	12		11		8		4
PHISCO	22		22		5		4

Current Receivables from/Payables to affiliates

The following tables present current receivables from affiliates and current payables to affiliates:

March 31, 2021

	Receivables from affiliates:
Payables to affiliates:	Generation			ComEd		PECO		BGE		Pepco		DPL		ACE		BSC		PHISCO		Other		Total
Generation				$	17	$	—	$	—	$	—	$	—	$	—	$	84	$	—	$	24	$	125
ComEd	$	50	(a)			—		—		—		—		—		49		—		5		104
PECO	15			—				—		—		—		—		24		—		7		46
BGE	11			1		—				—		—		—		30		—		1		43
PHI	—			1		—		—		—		—		—		7		—		10		18
Pepco	12			1		—		—				—		—		16		14		1		44
DPL	2			—		—		—		—				—		11		11		—		24
ACE	8			—		—		—		—		—				8		10		1		27
Other	8			1		—		—		—		—		1		—		—				10
Total	$	106		$	21	$	—	$	—	$	—	$	—	$	1	$	229	$	35	$	49	$	441

December 31, 2020

	Receivables from affiliates:
Payables to affiliates:	Generation			ComEd		PECO		BGE		Pepco		DPL		ACE		BSC		PHISCO		Other		Total
Generation				$	13	$	—	$	—	$	—	$	—	$	—	$	72	$	—	$	22	$	107
ComEd	$	78	(a)			—		—		—		—		—		59		—		9		146
PECO	17			1				—		—		—		—		28		—		4		50
BGE	11			—		—				—		—		—		47		—		3		61
PHI	—			—		—		—		—		—		—		4		—		11		15
Pepco	13			2		—		1				—		—		25		14		—		55
DPL	3			1		—		—		—				—		21		10		1		36
ACE	6			—		—		—		—		—				15		9		1		31
Other	25			5		2		2		2		1		6		—		—				43
Total	$	153		$	22	$	2	$	3	$	2	$	1	$	6	$	271	$	33	$	51	$	544

__________

(a)As of March 31, 2021 and December 31, 2020, Generation had a contract liability with ComEd for $24 million and $50 million, respectively, that was included in Other current liabilities on Generation’s Consolidated Balance Sheets. At March 31, 2021 and December 31, 2020, ComEd had a Current Payable to Generation of $26 million and $28 million, respectively, on its Consolidated Balance Sheets, which consisted of Generation’s Current Receivable from ComEd, partially offset by Generation’s contract liability with ComEd.

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. Generation, 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/Payables to affiliates

Generation has long-term payables to ComEd and PECO as a result of the nuclear decommissioning contractual construct whereby, to the extent NDT funds are greater than the underlying ARO at the end of decommissioning, such amounts are due back to ComEd and PECO, as applicable, for payment to their respective customers. See Note 10 — Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information.

The following table presents noncurrent receivables from affiliates at ComEd and PECO which are recorded as noncurrent payables to affiliates at Generation:

	March 31, 2021		December 31, 2020
ComEd	$	2,375	$	2,541
PECO	490		475

Long-term debt to financing trusts

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

	March 31, 2021						December 31, 2020
	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

Long-term debt to affiliates

In connection with the debt obligations assumed by Exelon as part of the Constellation merger, Exelon and subsidiaries of Generation (former Constellation subsidiaries) assumed intercompany loan agreements that mirror the terms and amounts of the third-party debt obligations of Exelon, resulting in intercompany notes payable included in Long-term debt to affiliates in Generation’s Consolidated Balance Sheets and intercompany notes receivable at Exelon Corporate.

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Planned Separation	3 Months Ended
	Mar. 31, 2021
Discontinued Operations and Disposal Groups [Abstract]
Planned Separation	Planned SeparationOn February 21, 2021, Exelon’s Board of Directors approved a plan to separate the Utility Registrants and Generation, creating two publicly traded companies. Under the separation plan, Exelon shareholders will retain their current shares of Exelon stock and receive a pro-rata distribution of shares of the new company’s stock in a transaction that is expected to be tax-free to Exelon and its shareholders for U.S. federal income tax purposes. The actual number of shares to be distributed to Exelon shareholders will be determined prior to closing. Exelon is targeting to complete the separation in the first quarter of 2022, subject to final approval by Exelon’s Board of Directors, a Form 10 registration statement being declared effective by the SEC, regulatory approvals, and satisfaction of other conditions. The transaction is subject to approval by the FERC, NRC, and NYPSC and receipt of a private letter ruling from the IRS and tax opinion from Exelon’s tax advisors. On February 25, 2021, Exelon and Generation filed applications with the FERC, NYPSC, and NRC seeking approvals for the separation of Generation. On March 25, 2021, Exelon filed a request for a private letter ruling with the IRS to confirm the tax-free treatment of the planned separation. Exelon and Generation expect a decision from the FERC and the IRS in the third quarter of 2021, the NRC in the fourth quarter of 2021, and have requested a decision from the NYPSC before the end of 2021 but cannot predict if the applications will be approved as filed. There can be no assurance that any separation transaction will ultimately occur or, if one does occur, of its terms or timing.

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Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2021

Accounting Policies [Abstract]

Description of Business and Basis of Presentation (All Registrants) [Policy Text Block]

Description of Business (All Registrants)

Exelon is a utility services holding company engaged in the generation, delivery and marketing of energy through Generation and the energy distribution and transmission businesses through ComEd, PECO, BGE, Pepco, DPL, and ACE.

Name of Registrant	Business	Service Territories
Exelon Generation Company, LLC	Generation, physical delivery and marketing of power across multiple geographical regions through its customer-facing business, Constellation, which sells electricity to both wholesale and retail customers. Generation also sells natural gas, renewable energy, and other energy-related products and services.	Five reportable segments: Mid-Atlantic, Midwest, New York, ERCOT, and Other Power Regions
Commonwealth Edison Company	Purchase and regulated retail sale of electricity	Northern Illinois, including the City of Chicago
	Transmission and distribution of electricity to retail customers
PECO Energy Company	Purchase and regulated retail sale of electricity and natural gas	Southeastern Pennsylvania, including the City of Philadelphia (electricity)
	Transmission and distribution of electricity and distribution of natural gas to retail customers	Pennsylvania counties surrounding the City of Philadelphia (natural gas)
Baltimore Gas and Electric Company	Purchase and regulated retail sale of electricity and natural gas	Central Maryland, including the City of Baltimore (electricity and natural gas)
	Transmission and distribution of electricity and distribution of natural gas to retail customers
Pepco Holdings LLC	Utility services holding company engaged, through its reportable segments Pepco, DPL, and ACE	Service Territories of Pepco, DPL, and ACE
Potomac Electric  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 (All Registrants)

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.

Through its business services subsidiary, BSC, Exelon provides its subsidiaries with a variety of support services at cost, including legal, human resources, financial, information technology, and supply management services. PHI also has a business services subsidiary, PHISCO, which provides a variety of support services at cost, including legal, accounting, engineering, customer operations, distribution and transmission planning, asset management, system operations, and power procurement, to PHI operating companies. The costs of BSC and PHISCO are directly charged or allocated to the applicable subsidiaries. The results of Exelon’s corporate operations are presented as “Other” within the consolidated financial statements and include intercompany eliminations unless otherwise disclosed.

The accompanying consolidated financial statements as of March 31, 2021 and for the three months ended March 31, 2021 and 2020 are unaudited but, in the opinion of the management of each Registrant include all adjustments that are considered necessary for a fair statement of the Registrants’ respective financial statements in accordance with GAAP. All adjustments are of a normal, recurring nature, except as otherwise disclosed. The

December 31, 2020 Consolidated Balance Sheets were derived from audited financial statements. 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, 2021. 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.

Revenue [Policy Text Block]

The Registrants recognize revenue from contracts with customers to depict the transfer of goods or services to customers at an amount that the entities expect to be entitled to in exchange for those goods or services. Generation’s primary sources of revenue include competitive sales of power, natural gas, and other energy-related products and services. The Utility Registrants’ primary sources of revenue include regulated electric and gas tariff sales, distribution, and transmission services.

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Regulatory Matters (Tables)

3 Months Ended

Mar. 31, 2021

Regulated Operations [Abstract]

Public Utilities Distribution Rate Cases [Table Text Block]

The following tables show the completed and pending distribution base rate case proceedings in 2021.

Completed Distribution Base Rate Case Proceedings

Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement (Decrease) Increase		Approved Revenue Requirement (Decrease) Increase		Approved ROE		Approval Date	Rate Effective Date
ComEd - Illinois(a)	April 16, 2020	Electric	$	(11)	$	(14)	8.38	%	December 9, 2020	January 1, 2021
BGE - Maryland(b)	May 15, 2020 (amended September 11, 2020)	Electric	137		81		9.50	%	December 16, 2020	January 1, 2021
		Natural Gas	91		21		9.65	%

__________

(a)ComEd's 2021 approved revenue requirement reflects an increase of $50 million for the initial year revenue requirement for 2021 and a decrease of $64 million related to the annual reconciliation for 2019. The revenue requirement for 2021 and the revenue requirement for 2019 provide for a weighted average debt and equity return on distribution rate base of 6.28%, inclusive of an allowed ROE of 8.38%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points.

(b)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 in 2021, 2022, and 2023, respectively, and natural gas revenue requirement increases of $53 million, $11 million, and $10 million in 2021, 2022, and 2023, respectively. However, the MDPSC utilized certain tax benefits to fully offset the increases in 2021 so that customer rates will remain unchanged from 2020 to 2021. The MDPSC has deferred a decision on whether to use certain tax benefits to offset the revenue requirement increases in 2022 and 2023 and BGE cannot predict the outcome.

Pending Distribution Base Rate Case Proceedings

Registrant/Jurisdiction	Filing Date	Service	Requested Revenue Requirement Increase		Requested ROE		Expected Approval Timing
ComEd - Illinois(a)	April 16, 2021	Electric	$	51	7.36	%	Fourth quarter of 2021
PECO - Pennsylvania	March 30, 2021	Electric	246		10.95	%	Fourth quarter of 2021
PECO - Pennsylvania	September 30, 2020	Natural Gas	69		10.95	%	Second quarter of 2021
Pepco - District of Columbia(b)	May 30, 2019 (amended June 1, 2020)	Electric	136		9.7	%	Second quarter of 2021
Pepco - Maryland(c)	October 26, 2020 (amended March 31, 2021)	Electric	104		10.2	%	Second quarter of 2021
DPL - Delaware(d)	March 6, 2020 (amended February 2, 2021)	Electric	23		10.3	%	Third quarter of 2021
ACE - New Jersey(e)	December 9, 2020 (amended February 26, 2021)	Electric	67		10.3	%	Fourth quarter of 2021

__________

(a)ComEd's 2022 requested revenue requirement reflects an increase of $40 million for the initial year revenue requirement for 2022 and an increase of $11 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 average monthly 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 average monthly yields for 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points.

(b)Pepco filed the multi-year plan enhanced proposal as an alternative to address the impacts of COVID-19. Reflects a three-year cumulative multi-year plan for 2020 through 2022 and requested revenue requirement increases of $73 million in 2022 and $63 million in 2023, to recover capital investments made during 2018 through 2020 and planned capital investments through the end of 2022.

(c)Reflects a three-year cumulative multi-year plan for April 1, 2021 through March 31, 2024 and total requested revenue requirement increases of $52 million effective April 1, 2023 and $52 million effective April 1, 2024 to recover capital investments made in 2019 and 2020 and planned capital investments through March 31, 2024.

(d)The rates went into effect on October 6, 2020, subject to refund.

(e)Requested increases are before New Jersey sales and use tax. ACE intends to put rates into effect on September 8, 2021 subject to refund.

Public Utilities Transmission Rate Filings [Table Text Block]

For 2021, the following total increases were included in ComEd’s electric transmission formula rate update. PECO, BGE, Pepco, DPL, and ACE intend to file by the required deadline for the annual update.

Registrant(a)	Initial Revenue Requirement Increase		Annual Reconciliation Increase		Total Revenue Requirement Increase		Allowed Return on Rate Base(b)		Allowed ROE(c)
ComEd	$	33	$	12	$	45	8.20	%	11.50	%

(a)Rates are effective June 30, 2021 - May 31, 2022, subject to review by interested parties pursuant to review protocols of ComEd's tariff.

(b)Represents the weighted average debt and equity return on transmission rate bases.

(c)As part of the FERC-approved settlements of ComEd’s 2007 rate case, the rate of return on common equity is 11.50%, inclusive of a 50-basis-point incentive adder for being a member of a RTO, and the common equity component of the ratio used to calculate the weighted average debt and equity return for the transmission formula rate is currently capped at 55%.

Public Utilities General Disclosures [Table Text Block]

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 Exelon's and the Utility Registrant's 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
March 31, 2021	$	49	$	—	$	—	$	43	$	6	$	3	$	3	$	—
December 31, 2020	51		(1)		—		45		7		4		3		—

_________

(a)Reflects ComEd's unrecognized equity returns/(losses) earned/(incurred) for ratemaking purposes on its electric distribution formula rate regulatory assets.

(b)BGE's authorized amounts capitalized for ratemaking purposes primarily relate to earnings on shareholders' investment on its AMI programs.

(c)Pepco's and DPL's authorized amounts capitalized for ratemaking purposes relate to earnings on shareholders' investment on their respective AMI Programs and Energy Efficiency and Demand Response Programs. The earnings on energy efficiency are on Pepco DC and DPL DE programs only.

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Revenue from Contracts with Customers (Tables)

3 Months Ended

Mar. 31, 2021

Contracts with Customers [Line Items]

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Table Text Block]

The following table shows the amounts of future revenues expected to be recorded in each year for performance obligations that are unsatisfied or partially unsatisfied as of March 31, 2021. 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 Generation's power and gas sales contracts as they contain variable volumes and/or variable pricing. This disclosure also 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.

	2021		2022		2023		2024		2025 and thereafter		Total
Exelon	$	233	$	100	$	56	$	41	$	330	$	760
Generation	286		131		56		35		243		751
PHI	7		8		8		6		87		116
Pepco	5		6		6		5		70		92
DPL	1		1		1		—		9		12
ACE	1		1		1		1		8		12

Contract Assets [Member]

Contracts with Customers [Line Items]

Contract with Customer, Contract Asset, Contract Liability, and Receivable [Table Text Block]

The following table provides a rollforward of the contract assets reflected in Exelon's and Generation's Consolidated Balance Sheets for the three months ended March 31, 2021 and 2020. The Utility Registrants do not have any contract assets.

	Exelon		Generation
Balance as of December 31, 2020	$	144	$	144
Amounts reclassified to receivables	(16)		(16)
Revenues recognized	13		13
Amounts previously held-for-sale	12		12
Balance as of March 31, 2021	$	153	$	153
	Exelon		Generation
Balance as of December 31, 2019	$	174	$	174
Amounts reclassified to receivables	(19)		(19)
Revenues recognized	17		17
Balance as of March 31, 2020	$	172	$	172

Contract Liabilities [Member]

Contracts with Customers [Line Items]

Contract with Customer, Contract Asset, Contract Liability, and Receivable [Table Text Block]

The following table provides a rollforward of the contract liabilities reflected in Exelon's, Generation's, PHI's, Pepco's, DPL's, and ACE's Consolidated Balance Sheets for the three months ended March 31, 2021 and 2020. As of March 31, 2021 and December 31, 2020, ComEd's, PECO's, and BGE's contract liabilities were immaterial.

	Exelon		Generation		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	151	$	84	$	118	$	94	$	12	$	12
Consideration received or due	20		31		—		—		—		—
Revenues recognized	(27)		(64)		(2)		(2)		—		—
Amounts previously held-for-sale	3		3		—		—		—		—
Balance as of March 31, 2021	$	147	$	54	$	116	$	92	$	12	$	12
	Exelon		Generation		PHI		Pepco		DPL		ACE
Balance as of December 31, 2019	$	33	$	71	$	—	$	—	$	—	$	—
Consideration received or due	20		55		—		—		—		—
Revenues recognized	(24)		(70)		—		—		—		—
Balance as of March 31, 2020	$	29	$	56	$	—	$	—	$	—	$	—

The following table reflects revenues recognized in the three months ended March 31, 2021 and 2020, which were included in contract liabilities at December 31, 2020 and 2019, respectively:

	Three Months Ended March 31,
	2021		2020
Exelon	$	17	$	9
Generation	39		19
PHI	2		—
Pepco	2		—

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Segment Information (Tables)

3 Months Ended

Mar. 31, 2021

Segment Tables [Line Items]

Analysis and reconciliation of reportable segment information

An analysis and reconciliation of the Registrants’ reportable segment information to the respective information in the consolidated financial statements for the three months ended March 31, 2021 and 2020 is as follows:

Three Months Ended March 31, 2021 and 2020

	Generation		ComEd		PECO		BGE		PHI		Other(a)		Intersegment Eliminations		Exelon
Operating revenues(b):
2021
Competitive businesses electric revenues	$	4,187	$	—	$	—	$	—	$	—	$	—	$	(293)	$	3,894
Competitive businesses natural gas revenues	1,326		—		—		—		—		—				1,326
Competitive businesses other revenues	46		—		—		—		—		—		(1)		45
Rate-regulated electric revenues	—		1,535		661		632		1,170		—		(10)		3,988
Rate-regulated natural gas revenues	—		—		228		342		71		—		(4)		637
Shared service and other revenues	—		—		—		—		3		491		(494)		—
Total operating revenues	$	5,559	$	1,535	$	889	$	974	$	1,244	$	491	$	(802)	$	9,890
2020
Competitive businesses electric revenues	$	3,752	$	—	$	—	$	—	$	—	$	—	$	(326)	$	3,426
Competitive businesses natural gas revenues	672		—		—		—		—		—		(3)		669
Competitive businesses other revenues	309		—		—		—		—		—		(1)		308
Rate-regulated electric revenues	—		1,439		604		613		1,104		—		(12)		3,748
Rate-regulated natural gas revenues	—		—		209		324		64		—		(2)		595
Shared service and other revenues	—		—		—		—		3		480		(482)		1
Total operating revenues	$	4,733	$	1,439	$	813	$	937	$	1,171	$	480	$	(826)	$	8,747
Intersegment revenues(c):
2021	$	295	$	6	$	2	$	6	$	3	$	487	$	(799)	$	—
2020	330		5		2		6		3		479		(824)		1
Depreciation and amortization:

	Generation		ComEd		PECO		BGE		PHI		Other(a)		Intersegment Eliminations		Exelon
2021	$	940	$	292	$	86	$	152	$	210	$	17	$	—	$	1,697
2020	304		273		86		143		194		21		—		1,021
Operating expenses:
2021	$	6,672	$	1,210	$	679	$	752	$	1,058	$	492	$	(781)	$	10,082
2020	4,400		1,151		625		688		1,000		481		(816)		7,529
Interest expense, net:
2021	$	72	$	96	$	38	$	34	$	67	$	79	$	—	$	386
2020	109		94		36		32		67		72		—		410
Income (loss) before income taxes:
2021	$	(947)	$	236	$	177	$	196	$	136	$	(80)	$	—	$	(282)
2020	(547)		204		155		222		119		(69)		1		85
Income Taxes:
2021	$	(179)	$	39	$	10	$	(13)	$	8	$	116	$	—	$	(19)
2020	(389)		36		15		41		11		(8)		—		(294)
Net income (loss):
2021	$	(769)	$	197	$	167	$	209	$	128	$	(196)	$	—	$	(264)
2020	(161)		168		140		181		108		(61)		1		376
Capital Expenditures:
2021	$	382	$	613	$	295	$	336	$	456	$	58	$	—	$	2,140
2020	558		506		259		283		376		34		—		2,016
Total assets:
March 31, 2021	$	47,326	$	34,825	$	12,937	$	11,759	$	24,387	$	8,788	$	(10,022)	$	130,000
December 31, 2020	48,094		34,466		12,531		11,650		23,736		9,005		(10,165)		129,317

__________

(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 17 — Supplemental Financial Information for additional information on total utility taxes.

(c)Intersegment revenues exclude sales to unconsolidated affiliates. The intersegment profit associated with Generation’s sale of certain products and services by and between Exelon’s segments is not eliminated in consolidation due to the recognition of intersegment profit in accordance with regulatory accounting guidance. For Exelon, these amounts are included in Operating revenues in the Consolidated Statements of Operations and Comprehensive Income. See Note 18 — Related Party Transactions for additional information on intersegment revenues.

PHI:

	Pepco		DPL		ACE		Other(a)		Intersegment Eliminations		PHI
Operating revenues(b):
2021
Rate-regulated electric revenues	$	553	$	311	$	310	$	—	$	(4)	$	1,170
Rate-regulated natural gas revenues	—		71		—		—		—		71
Shared service and other revenues	—		—		—		95		(92)		3
Total operating revenues	$	553	$	382	$	310	$	95	$	(96)	$	1,244
2020
Rate-regulated electric revenues	$	544	$	286	$	276	$	—	$	(2)	$	1,104
Rate-regulated natural gas revenues	—		64		—		—		—		64
Shared service and other revenues	—		—		—		93		(90)		3
Total operating revenues	$	544	$	350	$	276	$	93	$	(92)	$	1,171
Intersegment revenues(c):
2021	$	1	$	2	$	1	$	95	$	(96)	$	3
2020	1		2		1		92		(93)		3
Depreciation and amortization:
2021	$	102	$	53	$	47	$	8	$	—	$	210
2020	95		48		43		9		(1)		194
Operating expenses:
2021	$	466	$	309	$	282	$	97	$	(96)	$	1,058
2020	462		284		251		93		(90)		1,000
Interest expense, net:
2021	$	34	$	15	$	15	$	3	$	—	$	67
2020	34		16		15		3		(1)		67
Income (loss) before income taxes:
2021	$	65	$	61	$	14	$	(4)	$	—	$	136
2020(d)	57		52		14		(4)		—		119
Income Taxes:
2021	$	6	$	5	$	—	$	(3)	$	—	$	8
2020	5		7		1		(2)		—		11
Net income (loss):
2021	$	59	$	56	$	14	$	(1)	$	—	$	128
2020	52		45		13		(2)		—		108
Capital Expenditures:
2021	$	220	$	112	$	123	$	1	$	—	$	456
2020	180		95		101		—		—		376
Total assets:
March 31, 2021	$	9,493	$	5,232	$	4,679	$	5,020	$	(37)	$	24,387
December 31, 2020	9,264		5,140		4,286		5,079		(33)		23,736

__________

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

(b)Includes gross utility tax receipts from customers. The offsetting remittance of utility taxes to the governing bodies is recorded in expenses in the Registrants’ Consolidated Statements of Operations and Comprehensive Income. See Note 17 — Supplemental Financial Information for additional information on total utility taxes.

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

(d)The Income (loss) before income taxes in Other and Intersegment Eliminations have been adjusted by an offsetting $110 million in 2020.

Schedule of Revenue by Major Customers by Reporting Segments [Table Text Block]

Electric and Gas Revenue by Customer Class (Utility Registrants):

	Three Months Ended March 31, 2021
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Rate-regulated electric revenues
Residential	$	741	$	433	$	362	$	605	$	253	$	190	$	162
Small commercial & industrial	367		100		69		118		33		46		39
Large commercial & industrial	134		57		105		248		184		21		43
Public authorities & electric railroads	11		9		7		13		6		4		3
Other(a)	220		52		77		143		51		41		52
Total rate-regulated electric revenues(b)	$	1,473	$	651	$	620	$	1,127	$	527	$	302	$	299
Rate-regulated natural gas revenues
Residential	$	—	$	160	$	216	$	46	$	—	$	46	$	—
Small commercial & industrial	—		59		35		18		—		18		—
Large commercial & industrial	—		—		54		2		—		2		—
Transportation	—		7		—		4		—		4		—
Other(c)	—		2		31		1		—		1		—
Total rate-regulated natural gas revenues(d)	$	—	$	228	$	336	$	71	$	—	$	71	$	—
Total rate-regulated revenues from contracts with customers	$	1,473	$	879	$	956	$	1,198	$	527	$	373	$	299
Other revenues
Revenues from alternative revenue programs	$	54	$	10	$	18	$	46	$	26	$	9	$	11
Other rate-regulated electric revenues(e)	8		—		—		—		—		—		—
Other rate-regulated natural gas revenues(e)	—		—		—		—		—		—		—
Total other revenues	$	62	$	10	$	18	$	46	$	26	$	9	$	11
Total rate-regulated revenues for reportable segments	$	1,535	$	889	$	974	$	1,244	$	553	$	382	$	310

	Three Months Ended March 31, 2020
Revenues from contracts with customers	ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Rate-regulated electric revenues
Residential	$	701	$	382	$	339	$	534	$	236	$	161	$	137
Small commercial & industrial	362		99		67		115		35		43		37
Large commercial & industrial	134		53		103		253		188		23		42
Public authorities & electric railroads	13		7		7		15		9		3		3
Other(a)	211		58		79		169		60		54		55
Total rate-regulated electric revenues(b)	$	1,421	$	599	$	595	$	1,086	$	528	$	284	$	274
Rate-regulated natural gas revenues
Residential	$	—	$	150	$	206	$	40	$	—	$	40	$	—
Small commercial & industrial	—		51		34		17		—		17		—
Large commercial & industrial	—		—		51		1		—		1		—
Transportation	—		6		—		4		—		4		—
Other(c)	—		1		9		2		—		2		—
Total rate-regulated natural gas revenues(d)	$	—	$	208	$	300	$	64	$	—	$	64	$	—
Total rate-regulated revenues from contracts with customers	$	1,421	$	807	$	895	$	1,150	$	528	$	348	$	274
Other revenues
Revenues from alternative revenue programs	$	12	$	2	$	36	$	18	$	15	$	1	$	1
Other rate-regulated electric revenues(e)	6		3		3		3		1		1		1
Other rate-regulated natural gas revenues(e)	—		1		3		—		—		—		—
Total other revenues	$	18	$	6	$	42	$	21	$	16	$	2	$	2
Total rate-regulated revenues for reportable segments	$	1,439	$	813	$	937	$	1,171	$	544	$	350	$	276

__________

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

(b)Includes operating revenues from affiliates in 2021 and 2020 respectively of:

•$6 million, $5 million at ComEd

•$1 million, $2 million at PECO

•$2 million, $6 million at BGE

•$3 million, $3 million at PHI

•$1 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 2021 and 2020 respectively of:

•less than $1 million at PECO for both 2021 and 2020

•$4 million, $3 million at BGE

(e)Includes late payment charge revenues.

Year to Date [Member]

Segment Tables [Line Items]

Analysis and reconciliation of reportable segment revenues for Generation

The following tables disaggregate the Registrants' revenue recognized from contracts with customers into categories that depict how the nature, amount, timing, and uncertainty of revenue and cash flows are affected by economic factors. For Generation, the disaggregation of revenues reflects Generation’s two primary products of

power sales and natural gas sales, with further disaggregation of power sales provided by geographic region. For the Utility Registrants, the disaggregation of revenues reflects the two primary utility services of rate-regulated electric sales and rate-regulated natural gas sales (where applicable), with further disaggregation of these tariff sales provided by major customer groups. Exelon’s disaggregated revenues are consistent with Generation and the Utility Registrants, but exclude any intercompany revenues.

Competitive Business Revenues (Generation):

	Three Months Ended March 31, 2021
	Revenues from external customers(a)						Intersegment Revenues		Total Revenues
	Contracts with customers		Other(b)		Total
Mid-Atlantic	$	1,174	$	(14)	$	1,160	$	5	$	1,165
Midwest	1,009		(11)		998		—		998
New York	382		(45)		337		—		337
ERCOT	353		(101)		252		5		257
Other Power Regions	1,172		268		1,440		(10)		1,430
Total Competitive Businesses Electric Revenues	4,090		97		4,187		—		4,187
Competitive Businesses Natural Gas Revenues	864		462		1,326		—		1,326
Competitive Businesses Other Revenues(c)	89		(43)		46		—		46
Total Generation Consolidated Operating Revenues	$	5,043	$	516	$	5,559	$	—	$	5,559

	Three Months Ended March 31, 2020
	Revenues from external customers(a)						Intersegment revenues		Total Revenues
	Contracts with customers		Other(b)		Total
Mid-Atlantic	$	1,264	$	(96)	$	1,168	$	6	$	1,174
Midwest	944		64		1,008		(6)		1,002
New York	335		(21)		314		—		314
ERCOT	155		28		183		7		190
Other Power Regions	1,007		72		1,079		(7)		1,072
Total Competitive Businesses Electric Revenues	3,705		47		3,752		—		3,752
Competitive Businesses Natural Gas Revenues	503		169		672		—		672
Competitive Businesses Other Revenues(c)	99		210		309		—		309
Total Generation Consolidated Operating Revenues	$	4,307	$	426	$	4,733	$	—	$	4,733

__________

(a)Includes all wholesale and retail electric sales to third parties and affiliated sales to the Utility Registrants.

(b)Includes revenues from derivatives and leases.

(c)Other represents activities not allocated to a region. See text above for a description of included activities. Includes unrealized mark-to-market losses of $84 million and gains of $179 million in 2021 and 2020, respectively, and elimination of intersegment revenues.

Revenues net of purchased power and fuel expense (Generation):

	Three Months Ended March 31, 2021						Three Months Ended March 31, 2020
	RNF from external customers(a)		Intersegment RNF		Total RNF		RNF from external customers(a)		Intersegment RNF		Total RNF
Mid-Atlantic	$	562	$	5	$	567	$	559	$	8	$	567
Midwest	702		—		702		732		(5)		727
New York	240		2		242		189		4		193
ERCOT	(1,036)		(148)		(1,184)		76		4		80
Other Power Regions	250		(33)		217		177		(19)		158
Total Revenues net of purchased power and fuel expense for Reportable Segments	718		(174)		544		1,733		(8)		1,725
Other(b)	231		174		405		296		8		304
Total Generation Revenues net of purchased power and fuel expense	$	949	$	—	$	949	$	2,029	$	—	$	2,029

__________

(a)Includes purchases and sales from/to third parties and affiliated sales to the Utility Registrants.

(b)Other represents activities not allocated to a region. See text above for a description of included activities. Primarily includes:

•unrealized mark-to-market gains of $175 million and gains of $132 million in 2021 and 2020, respectively;

•accelerated nuclear fuel amortization associated with announced early plant retirements as discussed in Note 7 - Early Plant Retirements of $54 million in 2021; and

• the elimination of intersegment RNF.

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Accounts Receivable (Tables)

3 Months Ended

Mar. 31, 2021

Accounts, Notes, Loans and Financing Receivable, Gross, Allowance, and Net [Abstract]

Allowance for credit loss rollforward

The following tables present the rollforward of Allowance for Credit Losses on Customer Accounts Receivable.

	Three Months Ended March 31, 2021
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2020	$	366	$	32	$	97	$	116	$	35	$	86	$	32	$	22	$	32
Plus: Current period provision for expected credit losses(a)	104		34		21		20		9		20		11		6		3
Less: Write-offs, net of recoveries(b)	28		1		15		6		1		5		2		3		—
Balance as of March 31, 2021	$	442	$	65	$	103	$	130	$	43	$	101	$	41	$	25	$	35
	Three Months Ended March 31, 2020
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2019	$	243	$	80	$	59	$	55	$	12	$	37	$	13	$	11	$	13
Plus: Current period provision for expected credit losses	55		4		18		18		8		7		3		2		2
Less: Write-offs, net of recoveries(b)	20		3		6		7		2		2		1		—		1
Balance as of March 31, 2020	$	278	$	81	$	71	$	66	$	18	$	42	$	15	$	13	$	14

_________

(a)For Generation, primarily relates to the impacts of the February 2021 extreme cold weather event. See Note 3 — Regulatory Matters for additional information. For the Utility Registrants, the increase is primarily as a result of increased receivable balances due to the colder weather and the increased aging of receivables, the temporary suspension of customer disconnections for non-payment, temporary cessation of new late payment fees, and reconnection of service to customers previously disconnected due to COVID-19.

(b)Recoveries were not material to the Registrants.

The following tables present the rollforward of Allowance for Credit Losses on Other Accounts Receivable.

	Three Months Ended March 31, 2021
	Exelon		Generation		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 for expected credit losses	10		—		1		4		1		4		2		1		1
Less: Write-offs, net of recoveries(a)	2		—		—		1		1		—		—		—		—
Balance as of March 31, 2021	$	79	$	—	$	22	$	11	$	9	$	37	$	15	$	10	$	12
	Three Months Ended March 31, 2020
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Balance as of December 31, 2019	$	48	$	—	$	20	$	7	$	5	$	16	$	7	$	4	$	5
Plus: Current period provision for expected credit losses	8		—		3		1		2		2		1		—		1
Less: Write-offs, net of recoveries(a)	4		—		1		1		2		—		—		—		—
Balance as of March 31, 2020	$	52	$	—	$	22	$	7	$	5	$	18	$	8	$	4	$	6

_________

(a)Recoveries were not material to the Registrants.

Unbilled customer revenue

The following table provides additional information about unbilled customer revenues recorded in the Registrants' Consolidated Balance Sheets as of March 31, 2021 and December 31, 2020.

	Unbilled customer revenues(a)
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2021	$	1,178	$	671	$	161	$	102	$	126	$	118	$	58	$	38	$	22
December 31, 2020	998		258		218		147		197		178		87		62		29

_________

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

Purchases and sales of accounts receivable

The following table summarizes the impact of the sale of certain receivables:

	March 31, 2021		December 31, 2020
Derecognized receivables transferred at fair value	$	1,301	$	1,139
Cash proceeds received	900		500
DPP	401		639

	Three Months Ended March 31, 2021
Loss on sale of receivables(a)	$	17

_________

(a)Reflected in Operating and maintenance expense on Exelon's and Generation's Consolidated Statement of Operations and Comprehensive Income.

	Three Months Ended March 31, 2021
Proceeds from new transfers(a)	$	1,036
Cash collections received on DPP and reinvested in the Facility(b)	1,174
Cash collections reinvested in the Facility	2,210

_________

(a)Customer accounts receivable sold into the Facility were $2,375 million for the three months ended March 31, 2021.

(b)Does not include the $400 million in cash proceeds received from the Purchasers in the first quarter of 2021.

Generation is required, under supplier tariffs in ISO-NE, MISO, NYISO, and PJM, to sell customer and other receivables to utility companies, which include the Utility Registrants. The Utility Registrants are required, under separate legislation and regulations in Illinois, Pennsylvania, Maryland, District of Columbia, and New Jersey, to purchase certain receivables from alternative retail electric and, as applicable, natural gas suppliers that participate in the utilities' consolidated billing. The following tables present the total receivables purchased and sold.

	Three Months Ended March 31, 2021
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Total receivables purchased	$	1,011	$	—	$	266	$	290	$	199	$	268	$	166	$	56	$	46
Total receivables sold	69		81		—		—		—		—		—		—		—
Related party transactions:
Receivables purchased from Generation	—		—		—		—		12		—		—		—		—
Receivables sold to the Utility Registrants	—		12		—		—		—		—		—		—		—

	Three Months Ended March 31, 2020
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Total receivables purchased	$	781	$	—	$	280	$	284	$	195	$	264	$	165	$	53	$	46
Total receivables sold	507		749		—		—		—		—		—		—		—
Related party transactions:
Receivables purchased from Generation	—		—		34		67		69		72		51		13		8
Receivables sold to the Utility Registrants	—		242		—		—		—		—		—		—		—

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Early Plant Retirements (Tables)

3 Months Ended

Mar. 31, 2021

Property, Plant and Equipment [Abstract]

Restructuring and Related Costs [Table Text Block]

As a result of the decision to early retire Byron and Dresden, Exelon and Generation recognized certain one-time charges in the third and fourth quarters of 2020 related to materials and supplies inventory reserve adjustments, employee-related costs including severance benefit costs further discussed below, and construction work-in-progress impairments, among other items. In addition, as a result of the decisions to early retire Byron and Dresden, there are ongoing annual financial impacts stemming from shortening the expected economic useful lives of these nuclear plants primarily related to accelerated depreciation of plant assets (including any ARC), accelerated amortization of nuclear fuel, and changes in ARO accretion expense associated with the changes in decommissioning timing and cost assumptions to reflect an earlier retirement date. The total impact for the three months ended March 31, 2021 on Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income is summarized in the table below.

Income statement expense (pre-tax)	Three Months Ended March 31, 2021(a)
Depreciation and amortization
Accelerated depreciation(a)	$	620
Accelerated nuclear fuel amortization	54
Operating and maintenance
Other charges	2
Contractual offset(b)	(226)
Total	$	450

_________

(a)Includes the accelerated depreciation of plant assets including any ARC.

(b)Reflects contractual offset for ARO accretion and ARC depreciation. Based on the regulatory agreement with the ICC, decommissioning-related activities in the first quarter of 2021 have been offset within Exelon's and Generation's Consolidated Statements of Operations and Comprehensive Income. The offset in 2021 resulted in an equal adjustment to the noncurrent payables to ComEd at Generation and an adjustment to the regulatory liabilities at ComEd. See Note 10 - Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information.

Implications of Potential Early Plant Retirement on Balance Sheet [Table Text Block]

The following table provides the balance sheet amounts as of March 31, 2021 for Exelon's and Generation's significant assets and liabilities associated with the Braidwood and LaSalle nuclear plants. Current depreciation provisions are based on the estimated useful lives of these nuclear generating stations, which reflect the first renewal of the operating licenses.

	Braidwood		LaSalle		Total
Asset Balances
Materials and supplies inventory, net	$	83	$	103	$	186
Nuclear fuel inventory, net	165		264		429
Completed plant, net	1,379		1,566		2,945
Construction work in progress	33		70		103
Liability Balances
Asset retirement obligation	(577)		(964)		(1,541)
NRC License First Renewal Term	2046 (Unit 1)		2042 (Unit 1)
	2047 (Unit 2)		2043 (Unit 2)

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Nuclear Decommissioning (Tables)

3 Months Ended

Mar. 31, 2021

Schedule Of Nuclear Decommissioning [Line Items]

Schedule of Change in Asset Retirement Obligation [Table Text Block]

The following table provides a rollforward of the nuclear decommissioning ARO reflected in Exelon’s and Generation’s Consolidated Balance Sheets from December 31, 2020 to March 31, 2021:

Nuclear decommissioning ARO at December 31, 2020(a)	$	11,922
Accretion expense	124
Costs incurred related to decommissioning plants	(20)
Nuclear decommissioning ARO at March 31, 2021(a)	$	12,026

_________

(a)Includes $80 million as the current portion of the ARO at March 31, 2021 and December 31, 2020, which is included in Other current liabilities in Exelon’s and Generation’s Consolidated Balance Sheets.

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 2021

Significant Change in Unrecognized Tax Benefits is Reasonably Possible [Line Items]

Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]

The effective income tax rate from continuing operations varies from the U.S. federal statutory rate principally due to the following:

	Three Months Ended March 31, 2021
	Exelon(a)	Generation(a)	ComEd(b)	PECO(b)	BGE(b),(c)	PHI(b)	Pepco(b)	DPL(b)	ACE(b)
U.S. Federal statutory rate	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	14.6	4.4	6.8	(1.6)	(10.1)	6.1	5.5	6.4	6.9
Qualified NDT fund income	(18.4)	(5.5)	—	—	—	—	—	—	—
Amortization of investment tax credit, including deferred taxes on basis difference	2.4	0.6	(0.1)	—	(0.1)	(0.1)	—	(0.2)	(0.2)
Plant basis differences	8.8	—	(0.6)	(10.5)	(1.4)	(1.5)	(2.1)	(0.7)	(0.9)
Production tax credits and other credits	6.7	1.8	(0.2)	—	(0.4)	(0.2)	(0.2)	(0.1)	(0.3)
Noncontrolling interests	0.6	0.2	—	—	—	—	—	—	—
Excess deferred tax amortization	27.9	—	(6.9)	(3.2)	(15.5)	(19.3)	(15.1)	(18.5)	(28.7)
Other(d)	(56.9)	(3.6)	(3.5)	(0.1)	(0.1)	(0.1)	0.1	0.3	2.2
Effective income tax rate	6.7%	18.9%	16.5%	5.6%	(6.6)%	5.9%	9.2%	8.2%	—%

	Three Months Ended March 31, 2020
	Exelon(b)	Generation(e)	ComEd(b)	PECO(b)	BGE(b)	PHI(b)	Pepco(b)	DPL(b)	ACE(b)
U.S. Federal statutory rate	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%	21.0%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	34.0	0.7	8.3	0.1	5.7	5.8	4.7	6.6	6.7
Qualified NDT fund income	(235.8)	36.4	—	—	—	—	—	—	—
Amortization of investment tax credit, including deferred taxes on basis difference	(4.5)	0.5	(0.2)	—	(0.1)	(0.1)	—	(0.2)	(0.2)
Plant basis differences	(23.0)	—	(1.1)	(8.4)	(1.2)	(1.4)	(2.1)	(0.7)	(0.8)
Production tax credits and other credits	(9.9)	1.3	(0.2)	—	(0.2)	—	—	—	—
Noncontrolling interests	10.6	(1.6)	—	—	—	—	—	—	—
Excess deferred tax amortization	(71.7)	—	(10.5)	(3.0)	(7.3)	(15.5)	(14.2)	(12.7)	(18.8)
Tax Settlements	(79.1)	12.2	—	—	—	—	—	—	—
Other	12.5	0.6	0.3	—	0.6	(0.6)	(0.6)	(0.5)	(0.8)
Effective income tax rate	(345.9)%	71.1%	17.6%	9.7%	18.5%	9.2%	8.8%	13.5%	7.1%

__________

(a)Exelon and Generation recognized a loss before income taxes for the quarter ended March 31, 2021. As a result, positive percentages represent an income tax benefit for the period presented.

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

(c)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.

(d)For Exelon, "Other" is primarily driven by the consolidating income tax adjustment recorded at Exelon Corporate in the first quarter of 2021 that was required pursuant to GAAP interim reporting guidance. This incremental expense will reverse by year-end and will not have an impact on annual results.

(e)Generation recognized a loss before income taxes for the quarter ended March 31, 2020. As a result, positive percentages represent an income tax benefit for the period presented.

Schedule of Unrecognized Tax Benefits Roll Forward [Table Text Block]

PHI and ACE have the following unrecognized tax benefits as of March 31, 2021 and December 31, 2020. Exelon's, Generation's, ComEd's, PECO's, BGE's, Pepco's, and DPL's amounts are not material.

	PHI		ACE
March 31, 2021	$	52	$	15
December 31, 2020	52		15

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Retirement Benefits (Tables)

3 Months Ended

Mar. 31, 2021

Retirement Benefits [Abstract]

Calculation of Net Periodic Benefit Costs

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 months ended March 31, 2021 and 2020.

	Pension Benefits				OPEB
	Three Months Ended March 31,				Three Months Ended March 31,
	2021		2020		2021		2020
Components of net periodic benefit cost:
Service cost	$	110	$	97	$	21	$	23
Interest cost	161		189		28		38
Expected return on assets	(336)		(318)		(40)		(41)
Amortization of:
Prior service cost (credit)	1		1		(8)		(31)
Actuarial loss	150		128		9		12
Curtailment benefits	—		—		(1)		—
Net periodic benefit cost	$	86	$	97	$	9	$	1

Allocated Portion of Pension and Postretirement Benefit Costs

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 Generation and the Utility Registrants, the service cost and non-service cost components are included in Operating and maintenance expense and Property, plant, and equipment, net in their consolidated financial statements.

	Three Months Ended March 31,
Pension and OPEB Costs	2021		2020
Exelon	$	95	$	98
Generation	26		27
ComEd	32		28
PECO	2		1
BGE	15		16
PHI	12		17
Pepco	2		3
DPL	1		1
ACE	3		3

Defined Contribution Savings Plans

The Registrants participate in various 401(k) defined contribution savings plans that are sponsored by Exelon. The plans are 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 matching contributions to the savings plans for the three months ended March 31, 2021 and 2020, respectively.

	Three Months Ended March 31,
Savings Plans Matching Contributions	2021		2020
Exelon	$	33	$	33
Generation	13		13
ComEd	8		7
PECO	3		3
BGE	2		2
PHI	3		3
Pepco	1		1
DPL	1		1

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Derivative Financial Instruments (Tables)

3 Months Ended

Mar. 31, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Summary of the derivative fair value

The following table provides a summary of the derivative fair value balances recorded by Exelon, Generation, and ComEd as of March 31, 2021 and December 31, 2020:

	Exelon		Generation										ComEd
March 31, 2021	Total Derivatives		Economic Hedges		Proprietary Trading		Collateral(a)(b)		Netting(a)		Subtotal		Economic Hedges
Mark-to-market derivative assets (current assets)	$	569	$	2,566	$	28	$	24	$	(2,049)	$	569	$	—
Mark-to-market derivative assets (noncurrent assets)	488		1,400		5		45		(962)		488		—
Total mark-to-market derivative assets	1,057		3,966		33		69		(3,011)		1,057		—
Mark-to-market derivative liabilities (current liabilities)	(418)		(2,472)		(13)		49		2,049		(387)		(31)
Mark-to-market derivative liabilities (noncurrent liabilities)	(454)		(1,179)		(1)		28		962		(190)		(264)
Total mark-to-market derivative liabilities	(872)		(3,651)		(14)		77		3,011		(577)		(295)
Total mark-to-market derivative net assets (liabilities)	$	185	$	315	$	19	$	146	$	—	$	480	$	(295)

	Exelon		Generation										ComEd
December 31, 2020	Total Derivatives		Economic Hedges		Proprietary Trading		Collateral(a)(b)		Netting(a)		Subtotal		Economic Hedges
Mark-to-market derivative assets (current assets)	$	639	$	2,757	$	40	$	103	$	(2,261)	$	639	$	—
Mark-to-market derivative assets (noncurrent assets)	554		1,501		4		64		(1,015)		554		—
Total mark-to-market derivative assets	1,193		4,258		44		167		(3,276)		1,193		—
Mark-to-market derivative liabilities (current liabilities)	(293)		(2,629)		(23)		131		2,261		(260)		(33)
Mark-to-market derivative liabilities (noncurrent liabilities)	(472)		(1,335)		(2)		118		1,015		(204)		(268)
Total mark-to-market derivative liabilities	(765)		(3,964)		(25)		249		3,276		(464)		(301)
Total mark-to-market derivative net assets (liabilities)	$	428	$	294	$	19	$	416	$	—	$	729	$	(301)

_________

(a)Exelon and Generation net all available amounts allowed under the derivative authoritative guidance in the balance sheet. These amounts include unrealized derivative transactions with the same counterparty under legally enforceable master netting agreements and cash collateral. In some cases Exelon and Generation may have other offsetting exposures, subject to a master netting or similar agreement, such as trade receivables and payables, transactions that do not qualify as derivatives, letters of credit, and other forms of non-cash collateral. These amounts are not material and not reflected in the table above.

(b)Of the collateral posted, $148 million and $209 million represents variation margin on the exchanges as of March 31, 2021 and December 31, 2020 respectively.

Economic Hedges (Commodity Price Risk)

For the three months ended March 31, 2021 and 2020, Exelon and Generation recognized the following net pre-tax commodity mark-to-market gains (losses) which are also located in the Net fair value changes related to derivatives line in the Consolidated Statements of Cash Flows.

	Three Months Ended March 31,
	2021		2020
Income Statement Location	Gain (Loss)
Operating revenues	$	(83)	$	175
Purchased power and fuel	265		(47)
Total Exelon and Generation	$	182	$	128

Disclosure of Credit Derivatives [Table Text Block]

The following tables provide information on Generation’s credit exposure for all derivative instruments, NPNS, and payables and receivables, net of collateral and instruments that are subject to master netting agreements, as of March 31, 2021. The tables further delineate that exposure by credit rating of the counterparties and provide guidance on the concentration of credit risk to individual counterparties. The amounts in the tables below exclude credit risk exposure from individual retail counterparties, nuclear fuel procurement contracts, and exposure through RTOs, ISOs, NYMEX, ICE, NASDAQ, NGX, and Nodal commodity exchanges. 

Rating as of March 31, 2021	Total Exposure Before Credit Collateral		Credit Collateral(a)		Net Exposure		Number of Counterparties Greater than 10% of Net Exposure	Net Exposure of Counterparties Greater than 10% of Net Exposure
Investment grade	$	431	$	31	$	400	—	$	—
Non-investment grade	43		4		39
No external ratings
Internally rated — investment grade	146		1		145
Internally rated — non-investment grade	70		25		45
Total	$	690	$	61	$	629	—	$	—

Net Credit Exposure by Type of Counterparty	As of March 31, 2021
Investor-owned utilities, marketers, power producers	$	451
Energy cooperatives and municipalities	123
Other	55
Total	$	629

_________ 

(a)As of March 31, 2021, credit collateral held from counterparties where Generation had credit exposure included $32 million of cash and $29 million of letters of credit. The credit collateral does not include non-liquid collateral.

Fair Value of Derivatives with Credit- Risk Related Contingent Features [Table Text Block]

The aggregate fair value of all derivative instruments with credit-risk related contingent features in a liability position that are not fully collateralized (excluding transactions on the exchanges that are fully collateralized) is detailed in the table below:

Credit-Risk Related Contingent Features	March 31, 2021		December 31, 2020
Gross fair value of derivative contracts containing this feature(a)	$	(948)	$	(834)
Offsetting fair value of in-the-money contracts under master netting arrangements(b)	518		537
Net fair value of derivative contracts containing this feature(c)	$	(430)	$	(297)

_________

(a)Amount represents the gross fair value of out-of-the-money derivative contracts containing credit-risk related contingent features ignoring the effects of master netting agreements.

(b)Amount represents the offsetting fair value of in-the-money derivative contracts under legally enforceable master netting agreements with the same counterparty, which reduces the amount of any liability for which Generation could potentially be required to post collateral.

(c)Amount represents the net fair value of out-of-the-money derivative contracts containing credit-risk related contingent features after considering the mitigating effects of offsetting positions under master netting arrangements and reflects the actual net liability upon which any potential contingent collateral obligations would be based.

Cash Collateral and Letters of Credit on Derivative Contracts [Table Text Block]

As of March 31, 2021 and December 31, 2020, Exelon and Generation posted or held the following amounts of cash collateral and letters of credit on derivative contracts with external counterparties, after giving consideration to offsetting derivative and non-derivative positions under master netting agreements.

	March 31, 2021		December 31, 2020
Cash collateral posted	$	232	$	511
Letters of credit posted	242		226
Cash collateral held	101		110
Letters of credit held	41		40
Additional collateral required in the event of a credit downgrade below investment grade	1,379		1,432

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Debt and Credit Agreements (Tables)

3 Months Ended

Mar. 31, 2021

Line of Credit Facility [Line Items]

Schedule of Long-term Debt Instruments [Table Text Block]

During the three months ended March 31, 2021, the following long-term debt was issued:

Company	Type	Interest Rate		Maturity	Amount		Use of Proceeds
Exelon	Long-Term Software License Agreements	3.62	%	December 1, 2025	$	4	Procurement of software licenses.
Generation	Energy Efficiency Project Financing(a)	2.53	%	May 31, 2021	1		Funding to install energy conservation measures for the Fort AP Hill project.
ComEd	First Mortgage Bonds, Series 130	3.13	%	March 15, 2051	700		Repay a portion of outstanding commercial paper obligations and two outstanding term loans, and to fund other general corporate purposes.
PECO	First and Refunding Mortgage Bonds	3.05	%	March 15, 2051	375		Funding for general corporate purposes.
Pepco(b)	First Mortgage Bonds	2.32	%	March 30, 2031	150		Repay existing indebtedness and for general corporate purposes.
DPL	First Mortgage Bonds	3.24	%	March 30, 2051	125		Repay existing indebtedness and for general corporate purposes.
ACE	First Mortgage Bonds	2.30	%	March 15, 2031	350		Refinance existing indebtedness, repay outstanding commercial paper obligations, and for general corporate purposes.

__________

(a)For Energy Efficiency Project Financing, the maturity dates represent the expected date of project completion, upon which the respective customer assumes the outstanding debt.

(b)On March 30, 2021, Pepco entered into a purchase agreement of First Mortgage Bonds of $125 million at 3.29% due on September 28, 2051. The closing date of the issuance is expected to occur in September 2021.

Commercial Paper [Member]

Line of Credit Facility [Line Items]

Schedule of Commercial Paper Borrowings [Table Text Block]

The following table reflects the Registrants' commercial paper programs as of March 31, 2021 and December 31, 2020. PECO had no commercial paper borrowings as of both March 31, 2021 and December 31, 2020.

	Outstanding Commercial Paper as of				Average Interest Rate on Commercial Paper Borrowings as of
Commercial Paper Issuer	March 31, 2021		December 31, 2020		March 31, 2021		December 31, 2020
Exelon(a)(b)	$	1,628	$	1,031	0.52	%	0.25	%
Generation(b)	1,337		340		0.60	%	0.27	%
ComEd	135		323		0.16	%	0.23	%
BGE	156		—		0.15	%	—	%
PHI(c)	—		368		—	%	0.24	%
Pepco	—		35		—	%	0.22	%
DPL	—		146		—	%	0.24	%
ACE	—		187		—	%	0.25	%

__________

(a)Exelon Corporate had no outstanding commercial paper borrowings as of both March 31, 2021 and December 31, 2020.

(b)Higher outstanding commercial paper primarily driven by increased liquidity needs from the February 2021 extreme cold weather event. See Note 3 – Regulatory Matters for additional information.

(c)Represents the consolidated amounts of Pepco, DPL, and ACE.

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Fair Value of Financial Assets and Liabilities (Tables)

3 Months Ended

Mar. 31, 2021

Fair Value Disclosures [Abstract]

Fair Value of Financial Liabilities Recorded at Amortized Cost

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, SNF obligation, and trust preferred securities (long-term debt to financing trusts or junior subordinated debentures) as of March 31, 2021 and December 31, 2020. The Registrants have no financial liabilities classified as Level 1.

The carrying amounts of the Registrants’ short-term liabilities as presented on their Consolidated Balance Sheets are representative of their fair value (Level 2) because of the short-term nature of these instruments.

	March 31, 2021								December 31, 2020
	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	$	38,529	$	39,255	$	3,115	$	42,370	$	36,912	$	40,688	$	3,064	$	43,752
Generation	6,060		5,497		1,158		6,655		6,087		5,648		1,208		6,856
ComEd	9,674		10,853		—		10,853		8,983		11,117		—		11,117
PECO	4,125		4,491		50		4,541		3,753		4,553		50		4,603
BGE	3,665		3,991		—		3,991		3,664		4,366		—		4,366
PHI	7,577		6,050		1,907		7,957		7,006		6,099		1,806		7,905
Pepco	3,317		3,112		823		3,935		3,165		3,336		748		4,084
DPL	1,802		1,386		524		1,910		1,677		1,484		455		1,939
ACE	1,718		1,302		560		1,862		1,413		1,018		602		1,620
Long-Term Debt to Financing Trusts(a)
Exelon	$	390	$	—	$	465	$	465	$	390	$	—	$	467	$	467
ComEd	205		—		243		243		205		—		246		246
PECO	184		—		222		222		184		—		221		221
SNF Obligation
Exelon	$	1,208	$	979	$	—	$	979	$	1,208	$	909	$	—	$	909
Generation	1,208		979		—		979		1,208		909		—		909

__________

(a)Includes unamortized debt issuance costs which are not fair valued.

Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block]

Recurring Fair Value Measurements

The following tables present assets and liabilities measured and recorded at fair value in the Registrants' Consolidated Balance Sheets on a recurring basis and their level within the fair value hierarchy as of March 31, 2021 and December 31, 2020:

Exelon and Generation

	Exelon										Generation
As of March 31, 2021	Level 1		Level 2		Level 3		Not subject to leveling		Total		Level 1		Level 2		Level 3		Not subject to leveling		Total
Assets
Cash equivalents(a)	$	968	$	—	$	—	$	—	$	968	$	125	$	—	$	—	$	—	$	125
NDT fund investments
Cash equivalents(b)	509		95		—		—		604		509		95		—		—		604
Equities	4,439		1,574		—		1,555		7,568		4,439		1,574		—		1,555		7,568
Fixed income
Corporate debt(c)	—		1,023		283		—		1,306		—		1,023		283		—		1,306
U.S. Treasury and agencies	2,030		41		—		—		2,071		2,030		41		—		—		2,071
Foreign governments	—		51		—		—		51		—		51		—		—		51
State and municipal debt	—		40		—		—		40		—		40		—		—		40
Other	40		35		—		1,285		1,360		40		35		—		1,285		1,360
Fixed income subtotal	2,070		1,190		283		1,285		4,828		2,070		1,190		283		1,285		4,828
Private credit	—		—		196		617		813		—		—		196		617		813
Private equity	—		—		—		532		532		—		—		—		532		532
Real estate	—		—		—		686		686		—		—		—		686		686
NDT fund investments subtotal(d)(e)	7,018		2,859		479		4,675		15,031		7,018		2,859		479		4,675		15,031
Rabbi trust investments
Cash equivalents	60		—		—		—		60		4		—		—		—		4
Mutual funds	95		—		—		—		95		31		—		—		—		31
Fixed income	—		10		—		—		10		—		—		—		—		—
Life insurance contracts	—		89		35		—		124		—		29		—		—		29
Rabbi trust investments subtotal	155		99		35		—		289		35		29		—		—		64
Investments in equities(f)	177		—		—		—		177		177		—		—		—		177
Commodity derivative assets
Economic hedges	478		1,748		1,740		—		3,966		478		1,748		1,740		—		3,966
Proprietary trading	—		16		17		—		33		—		16		17		—		33
Effect of netting and allocation of collateral(g)(h)	(356)		(1,387)		(1,199)		—		(2,942)		(356)		(1,387)		(1,199)		—		(2,942)
Commodity derivative assets subtotal	122		377		558		—		1,057		122		377		558		—		1,057
DPP consideration	—		401		—		—		401		—		401		—		—		401

	Exelon										Generation
As of March 31, 2021	Level 1		Level 2		Level 3		Not subject to leveling		Total		Level 1		Level 2		Level 3		Not subject to leveling		Total
Total assets	8,440		3,736		1,072		4,675		17,923		7,477		3,666		1,037		4,675		16,855
Liabilities
Commodity derivative liabilities
Economic hedges	(359)		(1,642)		(1,945)		—		(3,946)		(359)		(1,642)		(1,650)		—		(3,651)
Proprietary trading	—		(9)		(5)		—		(14)		—		(9)		(5)		—		(14)
Effect of netting and allocation of collateral(g)(h)	252		1,532		1,304		—		3,088		252		1,532		1,304		—		3,088
Commodity derivative liabilities subtotal	(107)		(119)		(646)		—		(872)		(107)		(119)		(351)		—		(577)
Deferred compensation obligation	—		(146)		—		—		(146)		—		(43)		—		—		(43)
Total liabilities	(107)		(265)		(646)		—		(1,018)		(107)		(162)		(351)		—		(620)
Total net assets	$	8,333	$	3,471	$	426	$	4,675	$	16,905	$	7,370	$	3,504	$	686	$	4,675	$	16,235

	Exelon										Generation
As of December 31, 2020	Level 1		Level 2		Level 3		Not subject to leveling		Total		Level 1		Level 2		Level 3		Not subject to leveling		Total
Assets
Cash equivalents(a)	$	686	$	—	$	—	$	—	$	686	$	124	$	—	$	—	$	—	$	124
NDT fund investments
Cash equivalents(b)	210		95		—		—		305		210		95		—		—		305
Equities	3,886		2,077		—		1,562		7,525		3,886		2,077		—		1,562		7,525
Fixed income
Corporate debt(c)	—		1,485		285		—		1,770		—		1,485		285		—		1,770
U.S. Treasury and agencies	1,871		126		—		—		1,997		1,871		126		—		—		1,997
Foreign governments	—		56		—		—		56		—		56		—		—		56
State and municipal debt	—		101		—		—		101		—		101		—		—		101
Other	—		41		—		961		1,002		—		41		—		961		1,002
Fixed income subtotal	1,871		1,809		285		961		4,926		1,871		1,809		285		961		4,926
Private credit	—		—		212		629		841		—		—		212		629		841
Private equity	—		—		—		504		504		—		—		—		504		504
Real estate	—		—		—		679		679		—		—		—		679		679
NDT fund investments subtotal(d)(e)	5,967		3,981		497		4,335		14,780		5,967		3,981		497		4,335		14,780
Rabbi trust investments
Cash equivalents	60		—		—		—		60		4		—		—		—		4
Mutual funds	91		—		—		—		91		29		—		—		—		29
Fixed income	—		11		—		—		11		—		—		—		—		—
Life insurance contracts	—		87		34		—		121		—		28		—		—		28
Rabbi trust investments subtotal	151		98		34		—		283		33		28		—		—		61
Investments in equities(f)	195		—		—		—		195		195		—		—		—		195
Commodity derivative assets
Economic hedges	745		1,914		1,599		—		4,258		745		1,914		1,599		—		4,258
Proprietary trading	—		17		27		—		44		—		17		27		—		44
Effect of netting and allocation of collateral(g)(h)	(607)		(1,597)		(905)		—		(3,109)		(607)		(1,597)		(905)		—		(3,109)
Commodity derivative assets subtotal	138		334		721		—		1,193		138		334		721		—		1,193
DPP consideration	—		639		—		—		639		—		639		—		—		639
Total assets	7,137		5,052		1,252		4,335		17,776		6,457		4,982		1,218		4,335		16,992
Liabilities
Commodity derivative liabilities
Economic hedges	(682)		(1,928)		(1,655)		—		(4,265)		(682)		(1,928)		(1,354)		—		(3,964)
Proprietary trading	—		(21)		(4)		—		(25)		—		(21)		(4)		—		(25)
Effect of netting and allocation of collateral(g)(h)	540		1,918		1,067		—		3,525		540		1,918		1,067		—		3,525
Commodity derivative liabilities subtotal	(142)		(31)		(592)		—		(765)		(142)		(31)		(291)		—		(464)
Deferred compensation obligation	—		(145)		—		—		(145)		—		(42)		—		—		(42)
Total liabilities	(142)		(176)		(592)		—		(910)		(142)		(73)		(291)		—		(506)
Total net assets	$	6,995	$	4,876	$	660	$	4,335	$	16,866	$	6,315	$	4,909	$	927	$	4,335	$	16,486

__________    

(a)Exelon excludes cash of $1,273 million and $409 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $93 million and $59 million at March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $52 million and $53 million at March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. Generation excludes cash of $608 million and $171 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $29 million and $20 million at March 31, 2021 and December 31, 2020, respectively. 

(b)Includes $108 million and $116 million of cash received from outstanding repurchase agreements at March 31, 2021 and December 31, 2020, respectively, and is offset by an obligation to repay upon settlement of the agreement as discussed in (e) below.

(c)Includes investments in equities sold short of $(58) million and $(62) million as of March 31, 2021 and December 31, 2020, respectively, held in an investment vehicle primarily to hedge the equity option component of its convertible debt.

(d)Includes derivative assets of less than $1 million and $2 million, which have total notional amounts of $2,049 million and $1,043 million at March 31, 2021 and December 31, 2020, respectively. The notional principal amounts for these instruments provide one measure of the transaction volume outstanding as of the periods ended and do not represent the amount of Exelon and Generation's exposure to credit or market loss.

(e)Excludes net liabilities of $104 million and $181 million at March 31, 2021 and December 31, 2020, respectively, which include certain derivative assets that have notional amounts of $158 million and $104 million at March 31, 2021 and December 31, 2020, respectively. These items consist of receivables related to pending securities sales, interest and dividend receivables, repurchase agreement obligations, and payables related to pending securities purchases. The repurchase agreements are generally short-term in nature with durations generally of 30 days or less.

(f)Includes equity investments held by Generation which were previously designated as equity investments without readily determinable fair value but are now publicly traded and therefore have readily determinable fair values. Generation recorded the fair value of these investments in Other current assets on Exelon's and Generation's Consolidated Balance Sheets based on the quoted market prices of the stocks at March 31, 2021 and December 31, 2020, which resulted in unrealized gains of $95 million and $186 million within Other, net in Exelon's and Generation's Consolidated Statement of Operations and Comprehensive Income for the three months ended March 31, 2021 and for the year ended December 31, 2020, respectively.

(g)Collateral (received)/posted from counterparties, net of collateral paid to counterparties, totaled $(104) million, $145 million, and $105 million allocated to Level 1, Level 2, and Level 3 mark-to-market derivatives, respectively, as of March 31, 2021. Collateral (received)/posted from counterparties, net of collateral paid to counterparties, totaled $(67) million, $321 million, and $162 million allocated to Level 1, Level 2, and Level 3 mark-to-market derivatives, respectively, as of December 31, 2020.

(h)Of the collateral (received)/posted, $(148) million and $209 million represents variation margin on the exchanges as of March 31, 2021 and December 31, 2020, respectively.

As of March 31, 2021, Exelon and Generation have outstanding commitments to invest in private credit, private equity, and real estate investments of approximately $298 million, $239 million, and $344 million, respectively. These commitments will be funded by Generation’s existing NDT funds.

Exelon and Generation hold investments without readily determinable fair values with carrying amounts of $61 million and $50 million as of March 31, 2021, respectively. Changes in fair value, cumulative adjustments, and impairments were not material for the three months ended March 31, 2021.

ComEd, PECO, and BGE

	ComEd								PECO								BGE
As of March 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)	$	300	$	—	$	—	$	300	$	7	$	—	$	—	$	7	$	—	$	—	$	—	$	—
Rabbi trust investments
Mutual funds	—		—		—		—		9		—		—		9		11		—		—		11
Life insurance contracts	—		—		—		—		—		13		—		13		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		9		13		—		22		11		—		—		11
Total assets	300		—		—		300		16		13		—		29		11		—		—		11
Liabilities
Deferred compensation obligation	—		(8)		—		(8)		—		(9)		—		(9)		—		(6)		—		(6)
Mark-to-market derivative liabilities(b)	—		—		(295)		(295)		—		—		—		—		—		—		—		—
Total liabilities	—		(8)		(295)		(303)		—		(9)		—		(9)		—		(6)		—		(6)
Total net assets (liabilities)	$	300	$	(8)	$	(295)	$	(3)	$	16	$	4	$	—	$	20	$	11	$	(6)	$	—	$	5

	ComEd								PECO								BGE
As of December 31, 2020	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)	$	285	$	—	$	—	$	285	$	8	$	—	$	—	$	8	$	120	$	—	$	—	$	120
Rabbi trust investments
Mutual funds	—		—		—		—		9		—		—		9		10		—		—		10
Life insurance contracts	—		—		—		—		—		13		—		13		—		—		—		—
Rabbi trust investments subtotal	—		—		—		—		9		13		—		22		10		—		—		10
Total assets	285		—		—		285		17		13		—		30		130		—		—		130
Liabilities
Deferred compensation obligation	—		(8)		—		(8)		—		(9)		—		(9)		—		(5)		—		(5)
Mark-to-market derivative liabilities(b)	—		—		(301)		(301)		—		—		—		—		—		—		—		—
Total liabilities	—		(8)		(301)		(309)		—		(9)		—		(9)		—		(5)		—		(5)
Total net assets (liabilities)	$	285	$	(8)	$	(301)	$	(24)	$	17	$	4	$	—	$	21	$	130	$	(5)	$	—	$	125

__________

(a)ComEd excludes cash of $59 million and $83 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $40 million and $37 million at March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $43 million at both March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. PECO excludes cash of $48 million and $18 million at March 31, 2021 and December 31, 2020, respectively. BGE excludes cash of $21 million and $24 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $1 million at both March 31, 2021 and December 31, 2020.

(b)The Level 3 balance consists of the current and noncurrent liability of $31 million and $264 million, respectively, at March 31, 2021 and $33 million and $268 million, respectively, at December 31, 2020 related to floating-to-fixed energy swap contracts with unaffiliated suppliers.

PHI, Pepco, DPL, and ACE

	As of March 31, 2021								As of December 31, 2020
PHI	Level 1		Level 2		Level 3		Total		Level 1		Level 2		Level 3		Total
Assets
Cash equivalents(a)	$	527	$	—	$	—	$	527	$	86	$	—	$	—	$	86
Rabbi trust investments
Cash equivalents	53		—		—		53		55		—		—		55
Mutual funds	15		—		—		15		14		—		—		14
Fixed income	—		10		—		10		—		11		—		11
Life insurance contracts	—		26		35		61		—		26		34		60
Rabbi trust investments subtotal	68		36		35		139		69		37		34		140
Total assets	595		36		35		666		155		37		34		226
Liabilities
Deferred compensation obligation	—		(16)		—		(16)		—		(17)		—		(17)
Total liabilities	—		(16)		—		(16)		—		(17)		—		(17)
Total net assets	$	595	$	20	$	35	$	650	$	155	$	20	$	34	$	209

	Pepco								DPL								ACE
As of March 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)	$	128	$	—	$	—	$	128	$	50	$	—	$	—	$	50	$	349	$	—	$	—	$	349
Rabbi trust investments
Cash equivalents	53		—		—		53		—		—		—		—		—		—		—		—
Fixed income	—		2		—		2		—		—		—		—		—		—		—		—
Life insurance contracts	—		26		35		61		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	53		28		35		116		—		—		—		—		—		—		—		—
Total assets	181		28		35		244		50		—		—		50		349		—		—		349
Liabilities
Deferred compensation obligation	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total liabilities	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total net assets	$	181	$	26	$	35	$	242	$	50	$	—	$	—	$	50	$	349	$	—	$	—	$	349

	Pepco								DPL								ACE
As of December 31, 2020	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)	$	35	$	—	$	—	$	35	$	—	$	—	$	—	$	—	$	13	$	—	$	—	$	13
Rabbi trust investments
Cash equivalents	53		—		—		53		—		—		—		—		—		—		—		—
Fixed income	—		2		—		2		—		—		—		—		—		—		—		—
Life insurance contracts	—		26		34		60		—		—		—		—		—		—		—		—
Rabbi trust investments subtotal	53		28		34		115		—		—		—		—		—		—		—		—
Total assets	88		28		34		150		—		—		—		—		13		—		—		13
Liabilities
Deferred compensation obligation	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total liabilities	—		(2)		—		(2)		—		—		—		—		—		—		—		—
Total net assets	$	88	$	26	$	34	$	148	$	—	$	—	$	—	$	—	$	13	$	—	$	—	$	13

__________

(a)PHI excludes cash of $72 million and $74 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $5 million and none at March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $9 million and $10 million at March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets. Pepco excludes cash of $34 million and $30 million at March 31, 2021 and December 31, 2020, respectively, and restricted cash of $5 million and none at March 31, 2021 and December 31, 2020, respectively. DPL excludes cash of $14 million and $15 million at March 31, 2021 and December 31, 2020, respectively. ACE excludes cash of $17 million at both March 31, 2021 and December 31, 2020, respectively, and includes long-term restricted cash of $9 million and $10 million at March 31, 2021 and December 31, 2020, respectively, which is reported in Other deferred debits in the Consolidated Balance Sheets.

Fair Value Reconciliation of Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis

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 months ended March 31, 2021 and 2020:

	Exelon		Generation							ComEd			PHI and Pepco
Three months ended March 31, 2021	Total		NDT Fund Investments		Mark-to-Market Derivatives			Total Generation		Mark-to-Market Derivatives			Life Insurance Contracts		Eliminated in Consolidation
Balance as of December 31, 2020	$	660	$	497	$	430		$	927	$	(301)		$	34	$	—
Total realized / unrealized gains (losses)
Included in net income	(276)		1		(278)		(a)	(277)		—			1		—
Included in noncurrent payables to affiliates	—		1		—			1		—			—		(1)
Included in regulatory assets	7		—		—			—		6		(b)	—		1
Change in collateral	(57)		—		(57)			(57)		—			—		—
Purchases, sales, issuances and settlements
Purchases	109		—		109			109		—			—		—
Sales	1		—		1			1		—			—		—
Settlements	(20)		(20)		—			(20)		—			—		—
Transfers out of Level 3	2		—		2		(c)	2		—			—		—
Balance as of March 31, 2021	$	426	$	479	$	207		$	686	$	(295)		$	35	$	—
The amount of total (losses) gains included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of March 31, 2021	$	(147)	$	1	$	(149)		$	(148)	$	—		$	1	$	—

	Exelon		Generation							ComEd			PHI and Pepco
Three Months Ended March 31, 2020	Total		NDT Fund Investments		Mark-to-Market Derivatives			Total Generation		Mark-to-Market Derivatives			Life Insurance Contracts		Eliminated in Consolidation
Balance as of December 31, 2019	$	1,068	$	511	$	817		$	1,328	$	(301)		$	41	$	—
Total realized / unrealized gains (losses)
Included in net income	10		(1)		10		(a)	9		—			1		—
Included in noncurrent payables to affiliates	—		(1)		—			(1)		—			—		1
Included in regulatory assets	(14)		—		—			—		(13)		(b)	—		(1)
Change in collateral	1		—		1			1		—			—		—
Purchases, sales, issuances and settlements
Purchases	42		3		39			42		—			—		—
Sales	(22)		—		(22)			(22)		—			—		—
Settlements	(14)		(14)		—			(14)		—			—		—
Transfers into Level 3	2		—		2		(c)	2		—			—		—
Transfers out of Level 3	15		—		15		(c)	15		—			—		—
Balance as of March 31, 2020	$	1,088	$	498	$	862		$	1,360	$	(314)		$	42	$	—
The amount of total gains (losses) included in income attributed to the change in unrealized gains (losses) related to assets and liabilities as of March 31, 2020	$	187	$	(1)	$	187		$	186	$	—		$	1	$	—

__________

(a)Includes a reduction for the reclassification of $129 million and $177 million of realized losses due to the settlement of derivative contracts for the three months ended March 31, 2021 and 2020 respectively.

(b)Includes $2 million of decreases in fair value and an increase for realized losses due to settlements of $8 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended March 31, 2021. Includes $23 million of decrease in fair value and an increase for realized losses due to settlements of $10 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the three months ended March 31, 2020.

(c)Transfers into and out of Level 3 generally occur when the contract tenor becomes less and more observable respectively, primarily due to changes in market liquidity or assumptions for certain commodity contracts.

Total Realized and Unrealized Gains (Losses) Included in Income for Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis

The following tables present the income statement classification of the total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis during the three months ended March 31, 2021 and 2020:

	Exelon								Generation						PHI and Pepco
	Operating Revenues		Purchased Power and Fuel		Operating and Maintenance		Other, net		Operating Revenues		Purchased Power and Fuel		Other, net		Operating and Maintenance
Total (losses) gains for the three months ended March 31, 2021	$	(116)	$	(162)	$	1	$	1	$	(116)	$	(162)	$	1	$	1
Total unrealized (losses) gains for the three months ended March 31, 2021	(65)		(84)		1		1		(65)		(84)		1		1

	Exelon								Generation						PHI and Pepco
	Operating Revenues		Purchased Power and Fuel		Operating and Maintenance		Other, net		Operating Revenues		Purchased Power and Fuel		Other, net		Operating and Maintenance
Total gains (losses) for the three months ended March 31, 2020	$	72	$	(62)	$	1	$	(1)	$	72	$	(62)	$	(1)	$	1
Total unrealized gains (losses) gains for the three months ended March 31, 2020	205		(18)		1		(1)		205		(18)		(1)		1

Fair Value Reconciliation of Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis, Valuation Technique

Mark-to-Market Derivatives (Exelon, Generation and ComEd)

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

Type of trade	Fair Value at March 31, 2021		Fair Value at December 31, 2020		Valuation Technique	Unobservable Input	2021 Range & Arithmetic Average				2020 Range & Arithmetic Average
Mark-to-market derivatives — Economic Hedges (Exelon and Generation)(a)(b)	$	90	$	245	Discounted Cash Flow	Forward power price	$1.35	-	$235	$32	$2.25	-	$163	$30
						Forward gas price	$1.42	-	$8.18	$2.59	$1.57	-	$7.88	$2.59
					Option Model	Volatility percentage	11%	-	116%	27%	11%	-	237%	32%
Mark-to-market derivatives — Proprietary trading (Exelon and Generation)(a)(b)	$	12	$	23	Discounted Cash Flow	Forward power price	$9	-	$102	$30	$10	-	$106	$27
Mark-to-market derivatives (Exelon and ComEd)	$	(295)	$	(301)	Discounted Cash Flow	Forward heat rate(c)	8x	-	9x	8.85x	8x	-	9x	8.85x
						Marketability reserve	3%	-	8%	4.93%	3%	-	8%	4.93%
						Renewable factor	90%	-	123%	99%	91%	-	123%	99%

__________

(a)The valuation techniques, unobservable inputs, ranges and arithmetic averages are the same for the asset and liability positions.

(b)The fair values do not include cash collateral posted on level three positions of $105 million and $162 million as of March 31, 2021 and December 31, 2020, respectively.

(c)Quoted forward natural gas rates are utilized to project the forward power curve for the delivery of energy at specified future dates. The natural gas curve is extrapolated beyond its observable period to the end of the contract’s delivery.

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2021

Commitments and Contingencies Disclosure [Abstract]

PHI Merger Commitments

The following amounts represent total commitment costs that have been recorded since the acquisition date and the total remaining obligations for Exelon, PHI, Pepco, DPL, and ACE as of March 31, 2021:

Description	Exelon		PHI		Pepco		DPL		ACE
Total commitments	$	513	$	320	$	120	$	89	$	111
Remaining commitments(a)	79		64		53		7		4

__________

(a)Remaining commitments extend through 2026 and include rate credits, energy efficiency programs and delivery system modernization.

Commercial Commitments

The Registrants’ commercial commitments as of March 31, 2021, representing commitments potentially triggered by future events were as follows:

			Expiration within
	Total		2021		2022		2023		2024		2025		2026 and beyond
Exelon
Letters of credit	$	1,639	$	1,156	$	483	$	—	$	—	$	—	$	—
Surety bonds(a)	1,077		919		158		—		—		—		—
Financing trust guarantees	378		—		—		—		—		—		378
Guaranteed lease residual values(b)	29		—		3		4		6		5		11
Total commercial commitments	$	3,123	$	2,075	$	644	$	4	$	6	$	5	$	389
Generation
Letters of credit	$	1,623	$	1,141	$	482	$	—	$	—	$	—	$	—
Surety bonds(a)	932		794		138		—		—		—		—
Total commercial commitments	$	2,555	$	1,935	$	620	$	—	$	—	$	—	$	—
ComEd
Letters of credit	$	7	$	7	$	—	$	—	$	—	$	—	$	—
Surety bonds(a)	17		14		3		—		—		—		—
Financing trust guarantees	200		—		—		—		—		—		200
Total commercial commitments	$	224	$	21	$	3	$	—	$	—	$	—	$	200
PECO
Surety bonds(a)	$	2	$	2	$	—	$	—	$	—	$	—	$	—
Financing trust guarantees	178		—		—		—		—		—		178
Total commercial commitments	$	180	$	2	$	—	$	—	$	—	$	—	$	178
BGE
Letters of credit	$	3	$	2	$	1	$	—	$	—	$	—	$	—
Surety bonds(a)	3		3		—		—		—		—		—
Total commercial commitments	$	6	$	5	$	1	$	—	$	—	$	—	$	—
PHI
Surety bonds(a)	$	23	$	20	$	3	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	29		—		3		4		6		5		11
Total commercial commitments	$	52	$	20	$	6	$	4	$	6	$	5	$	11
Pepco
Surety bonds(a)	$	14	$	14	$	—	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	10		—		1		1		2		2		4
Total commercial commitments	$	24	$	14	$	1	$	1	$	2	$	2	$	4
DPL
Surety bonds(a)	$	5	$	2	$	3	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	12		—		1		2		3		2		4
Total commercial commitments	$	17	$	2	$	4	$	2	$	3	$	2	$	4
ACE
Surety bonds(a)	$	4	$	4	$	—	$	—	$	—	$	—	$	—
Guaranteed lease residual values(b)	7		—		1		1		1		1		3
Total commercial commitments	$	11	$	4	$	1	$	1	$	1	$	1	$	3

__________

(a)Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds.

(b)Represents the maximum potential obligation in the event that the fair value of certain leased equipment and fleet vehicles is zero at the end of the maximum lease term. The lease term associated with these assets ranges from 1 to 8 years. The maximum potential obligation at the end of the minimum lease term would be $73 million guaranteed by Exelon and PHI, of which $25 million, $30 million, and $18 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.

Accrued environmental liabilities

As of March 31, 2021 and December 31, 2020, the Registrants had accrued the following undiscounted amounts for environmental liabilities in Other current liabilities and Other deferred credits and other liabilities within their respective Consolidated Balance Sheets:

	March 31, 2021				December 31, 2020
	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	$	473	$	306	$	483	$	314
Generation	119		—		121		—
ComEd	281		280		293		293
PECO	23		21		23		21
BGE	6		5		2		—
PHI	44		—		44		—
Pepco	42		—		42		—
DPL	1		—		1		—
ACE	1		—		1		—

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Changes in Accumulated Other Comprehensive Income (Tables)

3 Months Ended

Mar. 31, 2021

Changes in Accumulated Other Comprehensive Income [Abstract]

Schedule of Changes in Accumulated Other Comprehensive Income (Loss)

The following tables present changes in Exelon's AOCI, net of tax, by component:

Three Months Ended March 31, 2021	Losses on Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items (a)		Foreign Currency Items		Total
Beginning balance	$	(5)	$	(3,372)	$	(23)	$	(3,400)
OCI before reclassifications	—		(2)		1		(1)
Amounts reclassified from AOCI	—		55		—		55
Net current-period OCI	—		53		1		54
Ending balance	$	(5)	$	(3,319)	$	(22)	$	(3,346)

Three Months Ended March 31, 2020	Losses on Cash Flow Hedges		Pension and Non-Pension Postretirement Benefit Plan Items (a)		Foreign Currency Items		Total
Beginning balance	$	(2)	$	(3,165)	$	(27)	$	(3,194)
OCI before reclassifications	(1)		(7)		(8)		(16)
Amounts reclassified from AOCI	—		37		—		37
Net current-period OCI	(1)		30		(8)		21
Ending balance	$	(3)	$	(3,135)	$	(35)	$	(3,173)

_________

(a)AOCI amounts are included in the computation of net periodic pension and OPEB cost. See Note 10 — Retirement Benefits for additional information. See Exelon's Statements of Operations and Comprehensive Income for individual components of AOCI.

Schedule Of Other Comprehensive Income (Loss) Tax

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

	Three Months Ended March 31,
	2021		2020
Pension and non-pension postretirement benefit plans:
Prior service benefit reclassified to periodic benefit cost	$	1	$	4
Actuarial loss reclassified to periodic benefit cost	(19)		(17)
Pension and non-pension postretirement benefit plans valuation adjustment	—		3

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Variable Interest Entities (Tables)

3 Months Ended

Mar. 31, 2021

Variable Interest Entity [Abstract]

VIE - Assets and Liabilities of VIEs which Creditors or Beneficiaries have no Recourse

Consolidated VIEs

The table below shows the carrying amounts and classification of the consolidated VIEs’ assets and liabilities included in the consolidated financial statements of Exelon, Generation, PHI, and ACE as of March 31, 2021 and December 31, 2020. The assets, except as noted in the footnotes to the table below, can only be used to settle obligations of the VIEs. The liabilities, except as noted in the footnote to the table below, are such that creditors, or beneficiaries, do not have recourse to the general credit of Exelon, Generation, PHI, and ACE.

	March 31, 2021								December 31, 2020
	Exelon		Generation		PHI (a)		ACE		Exelon		Generation		PHI (a)		ACE
Cash and cash equivalents	$	175	$	175	$	—	$	—	$	98	$	98	$	—	$	—
Restricted cash and cash equivalents	37		33		4		4		47		44		3		3
Accounts receivable
Customer	145		145		—		—		148		148		—		—
Other	35		35		—		—		36		36		—		—
Unamortized energy contract assets	22		22		—		—		22		22		—		—
Inventories, net
Materials and supplies	242		242		—		—		244		244		—		—
Assets held for sale(b)	—		—		—		—		101		101		—		—
Other current assets	448		443		5		—		674		669		5		—
Total current assets	1,104		1,095		9		4		1,370		1,362		8		3
Property, plant, and equipment, net	5,747		5,747		—		—		5,803		5,803		—		—
Nuclear decommissioning trust funds	3,089		3,089		—		—		3,007		3,007		—		—
Unamortized energy contract assets	243		243		—		—		249		249		—		—
Other noncurrent assets	47		38		9		9		52		42		10		10
Total noncurrent assets	9,126		9,117		9		9		9,111		9,101		10		10
Total assets(c)	$	10,230	$	10,212	$	18	$	13	$	10,481	$	10,463	$	18	$	13
Long-term debt due within one year	$	90	$	69	$	21	$	16	$	94	$	68	$	26	$	21
Accounts payable	95		95		—		—		81		81		—		—
Accrued expenses	67		67		—		—		70		70		—		—
Unamortized energy contract liabilities	3		3		—		—		4		4		—		—
Liabilities held for sale(b)	—		—		—		—		16		16		—		—
Other current liabilities	1		1		—		—		5		5		—		—
Total current liabilities	256		235		21		16		270		244		26		21
Long-term debt	861		861		—		—		889		889		—		—
Asset retirement obligations	2,347		2,347		—		—		2,318		2,318		—		—
Other noncurrent liabilities	116		116		—		—		129		129		—		—
Total noncurrent liabilities	3,324		3,324		—		—		3,336		3,336		—		—
Total liabilities(d)	$	3,580	$	3,559	$	21	$	16	$	3,606	$	3,580	$	26	$	21

_________

(a)Includes certain purchase accounting adjustments from the PHI merger not pushed down to ACE.

(b)In the fourth quarter of 2020, Generation entered into an agreement for the sale of a significant portion of Generation's solar business, and as a result of this transaction, Exelon and Generation reclassified the consolidated VIEs' solar assets and liabilities as held for sale. Completion of the transaction occurred in the first quarter of 2021. Refer to Note 2 - Mergers, Acquisitions, and Dispositions for additional information on the solar business.

(c)Exelon’s and Generation’s balances include unrestricted assets for current unamortized energy contract assets of $22 million and $22 million, non-current unamortized energy contract assets of $222 million and $249 million, Assets held for sale of $0 million and $9 million, and other unrestricted assets of $1 million and $1 million as of March 31, 2021 and December 31, 2020, respectively

(d)Exelon’s and Generation’s balances include liabilities with recourse of $2 million and $8 million as of March 31, 2021 and December 31, 2020, respectively.

VIE - Summary of Unconsolidated VIEs

The following table presents summary information about Exelon's and Generation’s significant unconsolidated VIE entities:

	March 31, 2021						December 31, 2020
	Commercial Agreement VIEs		Equity Investment VIEs		Total		Commercial Agreement VIEs		Equity Investment VIEs		Total
Total assets(a)	$	789	$	386	$	1,175	$	777	$	401	$	1,178
Total liabilities(a)	95		218		313		61		223		284
Exelon's ownership interest in VIE(a)	—		150		150		—		157		157
Other ownership interests in VIE(a)	694		18		712		716		21		737

_________

(a)These items represent amounts on the unconsolidated VIE balance sheets, not in Exelon’s or Generation’s Consolidated Balance Sheets. These items are included to provide information regarding the relative size of the unconsolidated VIEs. Exelon and Generation do not have any exposure to loss as they do not have a carrying amount in the equity investment VIEs as of March 31, 2021 and December 31, 2020.

XML

Supplemental Financial Information (Tables)

3 Months Ended

Mar. 31, 2021

Supplemental Financial Information [Abstract]

Components of Operating Lease Income

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

	Operating revenues
	Exelon		Generation		PHI		DPL
Three Months Ended March 31, 2021
Operating lease income	$	4	$	3	$	1	$	1
Variable lease income	64		64		—		—
Three Months Ended March 31, 2020
Operating lease income	$	5	$	3	$	1	$	1
Variable lease income	69		69		—		—

Taxes Other Than Income Taxes

	Taxes other than income taxes
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Utility taxes(a)	$	217	$	24	$	59	$	35	$	25	$	74	$	67	$	6	$	1
Property	154		68		8		4		42		32		21		10		1
Payroll	61		28		7		4		5		7		2		1		—
Three Months Ended March 31, 2020
Utility taxes(a)	$	218	$	26	$	60	$	31	$	26	$	75	$	69	$	6	$	—
Property	150		69		7		4		39		31		21		9		1
Payroll	63		31		7		4		4		8		2		1		1

__________

(a)Generation’s utility tax represents gross receipts tax related to its retail operations, and the Utility Registrants' utility taxes represents municipal and state utility taxes and gross receipts taxes related to their operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

Schedule of Other Nonoperating Income, by Component

	Other, net
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Decommissioning-related activities:
Net realized income on NDT funds(a)
Regulatory Agreement Units	$	291	$	291	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Non-Regulatory Agreement Units	203		203		—		—		—		—		—		—		—
Net unrealized gains on NDT funds
Regulatory Agreement Units	(82)		(82)		—		—		—		—		—		—		—
Non-Regulatory Agreement Units	(66)		(66)		—		—		—		—		—		—		—
Regulatory offset to NDT fund-related activities(b)	(167)		(167)		—		—		—		—		—		—		—
Decommissioning-related activities	179		179		—		—		—		—		—		—		—
AFUDC — Equity	28		—		4		6		7		11		9		1		1
Non-service net periodic benefit cost	20		—		—		—		—		—		—		—		—
Three Months Ended March 31, 2020
Decommissioning-related activities:
Net realized income on NDT funds(a)
Regulatory Agreement Units	$	47	$	47	$	—	$	—	$	—	$	—	$	—	$	—	$	—
Non-Regulatory Agreement Units	82		82		—		—		—		—		—		—		—
Net unrealized gains on NDT funds
Regulatory Agreement Units	(932)		(932)		—		—		—		—		—		—		—
Non-Regulatory Agreement Units	(706)		(706)		—		—		—		—		—		—		—
Regulatory offset to NDT fund-related activities(b)	709		709		—		—		—		—		—		—		—
Decommissioning-related activities	(800)		(800)		—		—		—		—		—		—		—
AFUDC — Equity	23		—		6		3		5		9		6		1		2
Non-service net periodic benefit cost	10		—		—		—		—		—		—		—		—

__________

(a)Realized income includes interest, dividends and realized gains and losses on sales of NDT fund investments.

(b)Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of income taxes related to all NDT fund activity for those units. See Note 10 — Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information regarding the accounting for nuclear decommissioning.

Cash Flow Supplemental Disclosures

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

	Depreciation, amortization and accretion
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Property, plant, and equipment(a)	$	1,522	$	928	$	239	$	82	$	106	$	154	$	67	$	42	$	37
Amortization of regulatory assets(a)	160		—		53		4		46		56		35		11		10
Amortization of intangible assets, net(a)	15		12		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(b)	4		3		—		—		—		—		—		—		—
Nuclear fuel(c)	276		276		—		—		—		—		—		—		—
ARO accretion(d)	127		127		—		—		—		—		—		—		—
Total depreciation, amortization and accretion	$	2,104	$	1,346	$	292	$	86	$	152	$	210	$	102	$	53	$	47
Three Months Ended March 31, 2020
Property, plant, and equipment(a)	$	856	$	290	$	228	$	79	$	97	$	144	$	64	$	38	$	34
Amortization of regulatory assets(a)	149		—		45		7		46		50		31		10		9
Amortization of intangible assets, net(a)	16		14		—		—		—		—		—		—		—
Amortization of energy contract assets and liabilities(b)	2		2		—		—		—		—		—		—		—
Nuclear fuel(c)	231		231		—		—		—		—		—		—		—
ARO accretion(d)	124		124		—		—		—		—		—		—		—
Total depreciation, amortization and accretion	$	1,378	$	661	$	273	$	86	$	143	$	194	$	95	$	48	$	43

__________

(a)Included in Depreciation and amortization in the Registrants' Consolidated Statements of Operations and Comprehensive Income.

(b)Included in Operating revenues or Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

(c)Included in Purchased power and fuel expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

(d)Included in Operating and maintenance expense in the Registrants’ Consolidated Statements of Operations and Comprehensive Income.

	Other non-cash operating activities
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
Three Months Ended March 31, 2021
Pension and non-pension postretirement benefit costs	$	95	$	26	$	32	$	2	$	14	$	12	$	2	$	1	$	3
Allowance for credit losses	85		34		13		24		4		10		5		4		1
Other decommissioning-related activity(a)	(322)		(332)		—		—		—		—		—		—		—
Energy-related options(b)	17		17		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(c)	(129)		—		(54)		(10)		(18)		(46)		(26)		(9)		(11)
Long-term incentive plan	32		—		—		—		—		—		—		—		—
Amortization of operating ROU asset	37		21		—		—		7		7		1		3		1
AFUDC - Equity	(28)		—		(4)		(6)		(7)		(11)		(9)		(1)		(1)
Three Months Ended March 31, 2020
Pension and non-pension postretirement benefit costs	$	98	$	27	$	28	$	1	$	15	$	17	$	3	$	1	$	3
Allowance for credit losses	45		4		7		17		7		10		4		3		3
Other decommissioning-related activity(a)	128		128		—		—		—		—		—		—		—
Energy-related options(b)	6		6		—		—		—		—		—		—		—
True-up adjustments to decoupling mechanisms and formula rates(d)	(71)		—		(17)		—		(35)		(19)		(15)		(4)		—
Long-term incentive plan	(7)		—		—		—		—		—		—		—		—
Amortization of operating ROU asset	51		35		—		—		8		5		2		2		1
AFUDC - Equity	(23)		—		(6)		(3)		(5)		(9)		(6)		(1)		(2)

__________

(a)Includes the elimination of decommissioning-related activities for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income, and income taxes related to all NDT fund activity for these units. See Note 10 — Asset Retirement Obligations of the Exelon 2020 Form 10-K for additional information regarding the accounting for nuclear decommissioning.

(b)Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations.

(c)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, and DPL, reflects the change in regulatory assets and liabilities associated with their decoupling mechanisms and transmission formula rates. For PECO and ACE, reflects the change in regulatory assets and liabilities associated with their transmission formula rates. See Note 3 — Regulatory Matters for additional information.

(d)For ComEd, reflects the true-up adjustments in regulatory assets and liabilities associated with its distribution and energy efficiency formula rates. For BGE, Pepco, and DPL, reflects the change in regulatory assets and liabilities associated with their decoupling mechanisms. See Note 3 — Regulatory Matters for additional information.

The following tables provide a reconciliation of cash, cash equivalents and restricted cash reported within the Registrants’ Consolidated Balance Sheets that sum to the total of the same amounts in their Consolidated Statements of Cash Flows.

	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2021
Cash and cash equivalents	$	1,908	$	721	$	86	$	48	$	21	$	558	$	134	$	64	$	353
Restricted cash and cash equivalents	374		41		270		7		1		37		33		—		4
Restricted cash included in other long-term assets	52		—		43		—		—		9		—		—		9
Total cash, restricted cash, and cash equivalents	$	2,334	$	762	$	399	$	55	$	22	$	604	$	167	$	64	$	366
December 31, 2020
Cash and cash equivalents	$	663	$	226	$	83	$	19	$	144	$	111	$	30	$	15	$	17
Restricted cash and cash equivalents	438		89		279		7		1		39		35		—		3
Restricted cash included in other long-term assets	53		—		43		—		—		10		—		—		10
Cash, restricted cash, and cash equivalents - Held for Sale	12		12		—		—		—		—		—		—		—
Total cash, restricted cash, and cash equivalents	$	1,166	$	327	$	405	$	26	$	145	$	160	$	65	$	15	$	30
March 31, 2020
Cash and cash equivalents	$	1,457	$	821	$	514	$	31	$	11	$	49	$	18	$	7	$	8
Restricted cash and cash equivalents	414		150		211		7		1		37		33		—		3
Restricted cash included in other long-term assets	121		—		108		—		—		12		—		—		12
Total cash, restricted cash, and cash equivalents	$	1,992	$	971	$	833	$	38	$	12	$	98	$	51	$	7	$	23
December 31, 2019
Cash and cash equivalents	$	587	$	303	$	90	$	21	$	24	$	131	$	30	$	13	$	12
Restricted cash and cash equivalents	358		146		150		6		1		36		33		—		2
Restricted cash included in other long-term assets	177		—		163		—		—		14		—		—		14
Total cash, restricted cash, and cash equivalents	$	1,122	$	449	$	403	$	27	$	25	$	181	$	63	$	13	$	28

For additional information on restricted cash see Note 1 — Significant Accounting Policies of the Exelon 2020 Form 10-K.

Supplemental Balance Sheet Disclosures

The following tables provide additional information about material items recorded in the Registrants' Consolidated Balance Sheets.

	Accrued expenses
	Exelon		Generation		ComEd		PECO		BGE		PHI		Pepco		DPL		ACE
March 31, 2021
Compensation-related accruals(a)	$	581	$	210	$	91	$	42	$	49	$	73	$	26	$	15	$	12
Taxes accrued	540		279		70		18		50		108		92		10		12
Interest accrued	424		76		65		36		41		79		37		20		20
December 31, 2020
Compensation-related accruals(a)	$	1,069	$	426	$	170	$	73	$	84	$	109	$	36	$	18	$	17
Taxes accrued	527		229		94		16		73		117		90		18		12
Interest accrued	331		44		109		37		46		51		26		7		12

__________

(a)Primarily includes accrued payroll, bonuses and other incentives, vacation and benefits.

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Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2021

Related Party Transactions [Abstract]

Operating Revenues and Purchased Power and Fuel

The following table presents Generation’s Operating revenues from affiliates, which are primarily recorded as Purchased power from affiliates and an immaterial amount recorded as Operating and maintenance expense from affiliates at the Utility Registrants:

	Three Months Ended March 31,
	2021		2020
Operating revenues from affiliates:
ComEd(a)(b)	$	78	$	90
PECO(c)	42		37
BGE(d)	72		99
PHI	100		103
Pepco(e)	75		79
DPL(f)	21		22
ACE(g)	4		2
Other	3		1
Total operating revenues from affiliates (Generation)	$	295	$	330

__________

(a)Generation has an ICC-approved RFP contract with ComEd to provide a portion of ComEd’s electricity supply requirements. Generation also sells RECs and ZECs to ComEd.

(b)For the three months ended March 31, 2021, ComEd’s Purchased power from Generation of $84 million is recorded as Operating revenues from ComEd of $78 million and as Purchased power and fuel from ComEd of $6 million at Generation. For the three months ended March 31, 2020, ComEd’s Purchased power from Generation of $97 million is recorded as Operating revenues from ComEd of $90 million and as Purchased power and fuel from ComEd of $7 million at Generation.

(c)Generation provides electric supply to PECO under contracts executed through PECO’s competitive procurement process. In addition, Generation has a ten-year agreement with PECO to sell solar AECs.

(d)Generation provides a portion of BGE’s energy requirements under its MDPSC-approved market-based SOS and gas commodity programs.

(e)Generation provides electric supply to Pepco under contracts executed through Pepco's competitive procurement process approved by the MDPSC and DCPSC.

(f)Generation provides a portion of DPL's energy requirements under its MDPSC and DPSC-approved market-based SOS commodity programs.

(g)Generation provides electric supply to ACE under contracts executed through ACE's competitive procurement process.

BSC and PHISCO Service Companies

The following table presents the service company costs allocated to the Registrants:

	Operating and maintenance from affiliates				Capitalized costs
	Three Months Ended March 31,				Three Months Ended March 31,
	2021		2020		2021		2020
Exelon
BSC					$	124	$	113
PHISCO					17		14
Generation
BSC	$	144	$	140	10		11
ComEd
BSC	71		72		45		42
PECO
BSC	39		37		17		16
BGE
BSC	43		41		20		28
PHI
BSC	39		37		32		16
PHISCO	—		—		17		14
Pepco
BSC	22		21		13		6
PHISCO	30		30		7		6
DPL
BSC	14		13		10		5
PHISCO	25		24		5		4
ACE
BSC	12		11		8		4
PHISCO	22		22		5		4

Current Receivables From/Payables To Affiliates

The following tables present current receivables from affiliates and current payables to affiliates:

March 31, 2021

	Receivables from affiliates:
Payables to affiliates:	Generation			ComEd		PECO		BGE		Pepco		DPL		ACE		BSC		PHISCO		Other		Total
Generation				$	17	$	—	$	—	$	—	$	—	$	—	$	84	$	—	$	24	$	125
ComEd	$	50	(a)			—		—		—		—		—		49		—		5		104
PECO	15			—				—		—		—		—		24		—		7		46
BGE	11			1		—				—		—		—		30		—		1		43
PHI	—			1		—		—		—		—		—		7		—		10		18
Pepco	12			1		—		—				—		—		16		14		1		44
DPL	2			—		—		—		—				—		11		11		—		24
ACE	8			—		—		—		—		—				8		10		1		27
Other	8			1		—		—		—		—		1		—		—				10
Total	$	106		$	21	$	—	$	—	$	—	$	—	$	1	$	229	$	35	$	49	$	441

December 31, 2020

	Receivables from affiliates:
Payables to affiliates:	Generation			ComEd		PECO		BGE		Pepco		DPL		ACE		BSC		PHISCO		Other		Total
Generation				$	13	$	—	$	—	$	—	$	—	$	—	$	72	$	—	$	22	$	107
ComEd	$	78	(a)			—		—		—		—		—		59		—		9		146
PECO	17			1				—		—		—		—		28		—		4		50
BGE	11			—		—				—		—		—		47		—		3		61
PHI	—			—		—		—		—		—		—		4		—		11		15
Pepco	13			2		—		1				—		—		25		14		—		55
DPL	3			1		—		—		—				—		21		10		1		36
ACE	6			—		—		—		—		—				15		9		1		31
Other	25			5		2		2		2		1		6		—		—				43
Total	$	153		$	22	$	2	$	3	$	2	$	1	$	6	$	271	$	33	$	51	$	544

__________

(a)As of March 31, 2021 and December 31, 2020, Generation had a contract liability with ComEd for $24 million and $50 million, respectively, that was included in Other current liabilities on Generation’s Consolidated Balance Sheets. At March 31, 2021 and December 31, 2020, ComEd had a Current Payable to Generation of $26 million and $28 million, respectively, on its Consolidated Balance Sheets, which consisted of Generation’s Current Receivable from ComEd, partially offset by Generation’s contract liability with ComEd.

Noncurrent Receivables from/Payables to affiliates

The following table presents noncurrent receivables from affiliates at ComEd and PECO which are recorded as noncurrent payables to affiliates at Generation:

	March 31, 2021		December 31, 2020
ComEd	$	2,375	$	2,541
PECO	490		475

Long Term Debt to Financing Trusts

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

	March 31, 2021						December 31, 2020
	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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Mergers, Acquisitions, and Dispositions - Narrative (Details) $ in Millions		3 Months Ended
	Apr. 01, 2014 USD ($)	Mar. 31, 2021 USD ($) MW	Dec. 31, 2020
Solar Business
Business Dispositions
Capacity Of Facility Of Company Owned Solar Distribution Generation Facilities | MW		360
Disposal Group, Including Discontinued Operation, Consideration		$ 810
Proceeds from Divestiture of Businesses		675
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent		125
Deconsolidation, Gain (Loss), Amount		68
Albany Green Energy biomass facility | Minimum [Member]
Business Dispositions
Impairment of Long-Lived Assets to be Disposed of		135
Albany Green Energy biomass facility | Maximum [Member]
Business Dispositions
Impairment of Long-Lived Assets to be Disposed of		$ 150
Exelon Generation Co L L C [Member] | Solar Business
Business Dispositions
Capacity Of Facility Of Company Owned Solar Distribution Generation Facilities | MW		360
Disposal Group, Including Discontinued Operation, Consideration		$ 810
Proceeds from Divestiture of Businesses		675
Disposal Group, Including Discontinued Operation, Liabilities, Noncurrent		125
Deconsolidation, Gain (Loss), Amount		68
Exelon Generation Co L L C [Member] | Albany Green Energy biomass facility | Minimum [Member]
Business Dispositions
Impairment of Long-Lived Assets to be Disposed of		135
Exelon Generation Co L L C [Member] | Albany Green Energy biomass facility | Maximum [Member]
Business Dispositions
Impairment of Long-Lived Assets to be Disposed of		$ 150
CENG [Member]
Business Acquisitions
Equity Method Investment, Ownership Percentage		50.01%	50.01%
Payments of Capital Distribution	$ 400
Due from Affiliates	400	$ 632
CENG Preferred Distribution Return		8.50%
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners		49.99%
CENG [Member] | Nine Mile Point
Business Acquisitions
Equity Method Investment, Ownership Percentage		82.00%
CENG [Member] | Exelon Generation Co L L C [Member]
Business Acquisitions
Equity Method Investment, Ownership Percentage		50.01%	50.01%
Payments of Capital Distribution	400
Due from Affiliates	$ 400	$ 632
CENG Preferred Distribution Return		8.50%
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners		49.99%
CENG [Member] | Exelon Generation Co L L C [Member] | Nine Mile Point
Business Acquisitions
Equity Method Investment, Ownership Percentage		82.00%

XML

Regulatory Matters - Narrative (Details) - USD ($)		3 Months Ended
	Feb. 15, 2021	Mar. 31, 2021
Texas-based generating assets
Regulatory Matters Additional Narrative Information [Line Items]
Operating and maintenance		$ 880,000,000
Market Payment Shortfall in Collections		28,000,000
Exelon Generation Co L L C [Member] | ERCOT
Regulatory Matters Additional Narrative Information [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 9,000
Market Payment Shortfall in Collections		2,900,000,000
Market-wide Limit Recovery of Default		2,500,000
Exelon Generation Co L L C [Member] | Texas-based generating assets
Regulatory Matters Additional Narrative Information [Line Items]
Operating and maintenance		880,000,000
Market Payment Shortfall in Collections		28,000,000
Commonwealth Edison Co [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets		106,000,000
Commonwealth Edison Co [Member] | Electric Distribution Formula Rate Annual Reconciliations [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets		55,000,000
Commonwealth Edison Co [Member] | Energy Efficiency Costs [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets		38,000,000
PECO Energy Co [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets		56,000,000
PECO Energy Co [Member] | Deferred Income Tax Charge [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets		48,000,000
PECO Energy Co [Member] | Vacation Accrual
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets		9,000,000
Baltimore Gas and Electric Company [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Assets
Increase (Decrease) in Regulatory Liabilities		(82,000,000)
Baltimore Gas and Electric Company [Member] | Deferred Income Tax Charge [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Liabilities		(93,000,000)
Baltimore Gas and Electric Company [Member] | electric energy and natural gas cost [Member]
Regulatory Matters Additional Narrative Information [Line Items]
Increase (Decrease) in Regulatory Liabilities		$ 9,000,000

XML

Regulatory Matters - Schedule of Completed Rate Cases (Details) - USD ($) $ in Millions					12 Months Ended
	Dec. 16, 2020	Dec. 09, 2020	Sep. 11, 2020	Apr. 16, 2020	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Commonwealth Edison Co [Member] | Illinois 2020 Electric Distribution Base Rate Case [Member]
Regulatory Matters Completed Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease)				$ (11)
Approved Revenue Requirement Increase (Decrease)		$ (14)
Approved Return on Equity, Percentage		8.38%
Public Utilities, Interim Rate Increase (Decrease), Amount		$ 50
Public Utilities Requested Rate Increase (Decrease), Prior Year Annual Reconciliation		$ (64)
Public Utilities, Approved Equity Capital Structure, Percentage		6.28%
Basis points for ComEd's Revenue Requirement		580
Baltimore Gas and Electric Company [Member] | Maryland 2020 Electric Distribution Base Rate Case [Member]
Regulatory Matters Completed Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease)			$ 137
Approved Revenue Requirement Increase (Decrease)	$ 81
Approved Return on Equity, Percentage	9.50%
Public Utilities, Interim Rate Increase (Decrease), Amount					$ 42	$ 39	$ 59
Baltimore Gas and Electric Company [Member] | Maryland 2020 Gas Distribution Base Rate Case [Member]
Regulatory Matters Completed Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease)			$ 91
Approved Revenue Requirement Increase (Decrease)	$ 21
Approved Return on Equity, Percentage	9.65%
Public Utilities, Interim Rate Increase (Decrease), Amount					$ 10	$ 11	$ 53

XML

Regulatory Matters - Schedule of Pending Rate Cases (Details) - USD ($) $ in Millions								12 Months Ended
	Mar. 31, 2021	Mar. 30, 2021	Feb. 26, 2021	Feb. 02, 2021	Sep. 30, 2020	Jun. 01, 2020	Apr. 16, 2020	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Commonwealth Edison Co [Member] | Illinois 2021 Electric Distribution Base Rate Case
Regulatory Matters Pending Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease)							$ 51
Requested Return on Equity, Percentage							7.36%
Public Utilities, Requested Rate Increase (Decrease), Initial Revenue Requirement, Amount							$ 40
Public Utilities Requested Rate Increase (Decrease), Prior Year Annual Reconciliation							$ 11
Requested Return on Distribution Rate Base, Percentage							5.72%
Basis points for ComEd's Revenue Requirement							580
Commonwealth Edison Co [Member] | Illinois 2021 Electric Distribution Base Rate Case 2020 Reconciliation
Regulatory Matters Pending Rate Cases [Line Items]
Requested Return on Equity, Percentage							7.29%
Requested Return on Distribution Rate Base, Percentage							5.69%
Basis points for ComEd's Revenue Requirement							580
Commonwealth Edison Co [Member] | Illinois 2021 Electric Distribution Base Rate Case 2020 Reconciliation | Performance Metrics Penalty
Regulatory Matters Pending Rate Cases [Line Items]
Basis points for ComEd's Revenue Requirement							7
PECO Energy Co [Member] | Pennsylvania 2021 Electric Distribution Base Rate Case
Regulatory Matters Pending Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease)		$ 246
Requested Return on Equity, Percentage		10.95%
PECO Energy Co [Member] | Pennsylvania 2020 Natural Gas Distribution Base Rate Case
Regulatory Matters Pending Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease)					$ 69
Requested Return on Equity, Percentage					10.95%
Potomac Electric Power Company [Member] | District of Columbia 2019 Electric Distribution Base Rate Case [Member]
Regulatory Matters Pending Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease), Amended						$ 136			$ 63	$ 73
Requested Return on Equity, Percentage						9.70%
Potomac Electric Power Company [Member] | Maryland 2020 Electric Distribution Base Rate Case [Member]
Regulatory Matters Pending Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease), Amended	$ 104							$ 52	$ 52
Requested Return on Equity, Percentage	10.20%
Delmarva Power and Light Company [Member] | Delaware 2020 Electric Distribution Base Rate Case [Member]
Regulatory Matters Pending Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease), Amended				$ 23
Requested Return on Equity, Percentage				10.30%
Atlantic City Electric Company [Member] | New Jersey 2020 Electric Distribution Base Rate Case
Regulatory Matters Pending Rate Cases [Line Items]
Requested Revenue Requirement Increase (Decrease), Amended			$ 67
Requested Return on Equity, Percentage			10.30%

XML

Regulatory Matters - Annual Electric Transmission Fillings (Details) - Commonwealth Edison Co [Member] - 2021 Transmission Formula Rate Annual Update [Domain] $ in Millions	Apr. 16, 2021 USD ($)
Public Utilities, General Disclosures [Line Items]
Public Utilities, Requested Rate Increase (Decrease), Amount	$ 33
Annual Reconciliation Decrease	12
Public Utilities, Requested Rate Increase (Decrease), Amended, Amount	$ 45
Public Utilities, Approved Equity Capital Structure, Percentage	8.20%
Public Utilities, Approved Return on Equity, Percentage	11.50%
Cap on Equity Component of Rate of Return on Common Equity in Federal Energy Regulatory Committee Complaint	55.00%

XML

Regulatory Matters - Capitalized Ratemaking Amount Not Recognized (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	$ 49	$ 51
Commonwealth Edison Co [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	0	(1)
PECO Energy Co [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	0	0
Baltimore Gas and Electric Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	43	45
Pepco Holdings LLC [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	6	7
Potomac Electric Power Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	3	4
Delmarva Power and Light Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	3	3
Atlantic City Electric Company [Member]
Public Utility, Property, Plant and Equipment [Line Items]
Public Utilities, Amount of Allowance for Earnings on Equity Capitalized for Rate Making Purposes	$ 0	$ 0

XML

Revenue from Contracts with Customers - Change in Contract with Customer, Asset and Liability (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Contract Asset [Roll Forward]
Beginning Balance - Contract Assets	$ 144	$ 174
Consideration (received) due, contract assets	(16)	(19)
Revenues recognized, contract assets	13	17
Contract with Customer, Asset, Increase (Decrease) for Contract Acquired in Business Combination	12
Ending Balance - Contract Assets	153	172
Contract Liabilities [Roll Forward]
Beginning Balance - Contract Liabilities	151	33
Consideration received (due), contract liabilities	20	20
Revenues recognized, contract liabilities	(27)	(24)
Contract with Customer, Liability, Increase (Decrease) for Contract Acquired in Business Combination	3
Ending Balance - Contract Liabilities	147	29
Contract with Customer, Performance Obligation Satisfied in Previous Period	17	9
Exelon Generation Co L L C [Member]
Contract Asset [Roll Forward]
Beginning Balance - Contract Assets	144	174
Consideration (received) due, contract assets	(16)	(19)
Revenues recognized, contract assets	13	17
Contract with Customer, Asset, Increase (Decrease) for Contract Acquired in Business Combination	12
Ending Balance - Contract Assets	153	172
Contract Liabilities [Roll Forward]
Beginning Balance - Contract Liabilities	84	71
Consideration received (due), contract liabilities	31	55
Revenues recognized, contract liabilities	(64)	(70)
Contract with Customer, Liability, Increase (Decrease) for Contract Acquired in Business Combination	3
Ending Balance - Contract Liabilities	54	56
Contract with Customer, Performance Obligation Satisfied in Previous Period	39	19
Pepco Holdings LLC [Member]
Contract Liabilities [Roll Forward]
Beginning Balance - Contract Liabilities	118	0
Consideration received (due), contract liabilities	0	0
Revenues recognized, contract liabilities	(2)	0
Contract with Customer, Liability, Increase (Decrease) for Contract Acquired in Business Combination	0
Ending Balance - Contract Liabilities	116	0
Contract with Customer, Performance Obligation Satisfied in Previous Period	2	0
Potomac Electric Power Company [Member]
Contract Liabilities [Roll Forward]
Beginning Balance - Contract Liabilities	94	0
Consideration received (due), contract liabilities	0	0
Revenues recognized, contract liabilities	(2)	0
Contract with Customer, Liability, Increase (Decrease) for Contract Acquired in Business Combination	0
Ending Balance - Contract Liabilities	92	0
Contract with Customer, Performance Obligation Satisfied in Previous Period	2	0
Delmarva Power and Light Company [Member]
Contract Liabilities [Roll Forward]
Beginning Balance - Contract Liabilities	12	0
Consideration received (due), contract liabilities	0	0
Revenues recognized, contract liabilities	0	0
Contract with Customer, Liability, Increase (Decrease) for Contract Acquired in Business Combination	0
Ending Balance - Contract Liabilities	12	0
Atlantic City Electric Company [Member]
Contract Liabilities [Roll Forward]
Beginning Balance - Contract Liabilities	12	0
Consideration received (due), contract liabilities	0	0
Revenues recognized, contract liabilities	0	0
Contract with Customer, Liability, Increase (Decrease) for Contract Acquired in Business Combination	0
Ending Balance - Contract Liabilities	$ 12	$ 0

XML

Revenue from Contracts with Customers - Performance Obligations (Details) $ in Millions	Mar. 31, 2021 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 760
Exelon Generation Co L L C [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	751
Pepco Holdings LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	116
Potomac Electric Power Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	92
Delmarva Power and Light Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	12
Atlantic City Electric Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	12
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	233
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Exelon Generation Co L L C [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	286
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Pepco Holdings LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	7
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Potomac Electric Power Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	5
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Delmarva Power and Light Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01 | Atlantic City Electric Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	100
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Exelon Generation Co L L C [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	131
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Pepco Holdings LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	8
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Potomac Electric Power Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	6
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Delmarva Power and Light Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01 | Atlantic City Electric Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	56
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Exelon Generation Co L L C [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	56
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Pepco Holdings LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	8
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Potomac Electric Power Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	6
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Delmarva Power and Light Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01 | Atlantic City Electric Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	41
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Exelon Generation Co L L C [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	35
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Pepco Holdings LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	6
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Potomac Electric Power Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	5
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Delmarva Power and Light Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	0
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01 | Atlantic City Electric Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	1
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	330
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Exelon Generation Co L L C [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	243
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Pepco Holdings LLC [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	87
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Potomac Electric Power Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	70
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Delmarva Power and Light Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	9
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01 | Atlantic City Electric Company [Member]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, Remaining Performance Obligation, Amount	$ 8

XML

Segment Information - Narrative (Details)	3 Months Ended
	Mar. 31, 2021 Reportable_segment
Segment Reporting Information [Line Items]
Number of reportable segments	11
Exelon Generation Co L L C [Member]
Segment Reporting Information [Line Items]
Number of reportable segments	5
Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Number of reportable segments	3

XML

Segment Information - Reconciliation to Consolidated Financial Statements (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Segment Reporting Information [Line Items]
Revenues		$ 9,890	$ 8,747
Revenue from Related Parties		0	1
Depreciation and Amortization		1,697	1,021
Operating Expenses		10,082	7,529
Interest expense, net		386	410
Income (Loss) before income taxes		(282)	85
Income taxes		(19)	(294)
Net income (loss)		(264)	376
Capital expenditures		2,140	2,016
Assets	[1]	130,000		$ 129,317
Exelon Generation Co L L C [Member]
Segment Reporting Information [Line Items]
Revenues		5,559	4,733
Revenue from Related Parties		295	330
Income (Loss) before income taxes		(947)	(547)
Income taxes		(179)	(389)
Net income (loss)		(769)	(161)
Capital expenditures		382	558
Assets	[2]	47,326		48,094
Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenues		1,244	1,171
Revenue from Related Parties		3	3
Income (Loss) before income taxes		136	119
Income taxes		8	11
Net income (loss)		128	108
Capital expenditures		456	376
Assets	[3]	24,387		23,736
Commonwealth Edison Co Affiliate [Member] | Exelon Generation Co L L C [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		78	90
PECO Energy Co Affiliate [Member] | Exelon Generation Co L L C [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		42	37
Baltimore Gas And Electric Company Affiliate [Member] | Exelon Generation Co L L C [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		72	99
Operating Segment [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		46	18
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues		(802)	(826)
Revenue from Related Parties		(799)	(824)
Depreciation and Amortization		0	0
Operating Expenses		(781)	(816)
Interest expense, net		0	0
Income (Loss) before income taxes		0	1
Income taxes		0	0
Net income (loss)		0	1
Capital expenditures		0	0
Assets		(10,022)		(10,165)
Intersegment Eliminations [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenues		(96)	(92)
Revenue from Related Parties		(96)	(93)
Depreciation and Amortization		0	(1)
Operating Expenses		(96)	(90)
Interest expense, net		0	(1)
Income (Loss) before income taxes		0	0
Income taxes		0	0
Net income (loss)		0	0
Capital expenditures		0	0
Assets		(37)		(33)
Exelon Generation Co L L C [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues		5,559	4,733
Depreciation and Amortization		940	304
Operating Expenses		6,672	4,400
Interest expense, net		72	109
Income (Loss) before income taxes		(947)	(547)
Income taxes		(179)	(389)
Net income (loss)		(769)	(161)
Capital expenditures		382	558
Assets		47,326		48,094
Exelon Generation Co L L C [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		295	330
Commonwealth Edison Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues		1,535	1,439
Depreciation and Amortization		292	273
Operating Expenses		1,210	1,151
Interest expense, net		96	94
Income (Loss) before income taxes		236	204
Income taxes		39	36
Net income (loss)		197	168
Capital expenditures		613	506
Assets		34,825		34,466
Commonwealth Edison Co [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		6	5
PECO Energy Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues		889	813
Depreciation and Amortization		86	86
Operating Expenses		679	625
Interest expense, net		38	36
Income (Loss) before income taxes		177	155
Income taxes		10	15
Net income (loss)		167	140
Capital expenditures		295	259
Assets		12,937		12,531
PECO Energy Co [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		2	2
Baltimore Gas and Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues		974	937
Depreciation and Amortization		152	143
Operating Expenses		752	688
Interest expense, net		34	32
Income (Loss) before income taxes		196	222
Income taxes		(13)	41
Net income (loss)		209	181
Capital expenditures		336	283
Assets		11,759		11,650
Baltimore Gas and Electric Company [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		6	6
Pepco Holdings LLC [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues		1,244	1,171
Depreciation and Amortization		210	194
Operating Expenses		1,058	1,000
Interest expense, net		67	67
Income (Loss) before income taxes		136	119
Income taxes		8	11
Net income (loss)		128	108
Capital expenditures		456	376
Assets		24,387		23,736
Pepco Holdings LLC [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		3	3
Potomac Electric Power Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues		553	544
Depreciation and Amortization		102	95
Operating Expenses		466	462
Interest expense, net		34	34
Income (Loss) before income taxes		65	57
Income taxes		6	5
Net income (loss)		59	52
Capital expenditures		220	180
Assets		9,493		9,264
Potomac Electric Power Company [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		1	1
Delmarva Power and Light Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues		382	350
Depreciation and Amortization		53	48
Operating Expenses		309	284
Interest expense, net		15	16
Income (Loss) before income taxes		61	52
Income taxes		5	7
Net income (loss)		56	45
Capital expenditures		112	95
Assets		5,232		5,140
Delmarva Power and Light Company [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		2	2
Atlantic City Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenues		310	276
Depreciation and Amortization		47	43
Operating Expenses		282	251
Interest expense, net		15	15
Income (Loss) before income taxes		14	14
Income taxes		0	1
Net income (loss)		14	13
Capital expenditures		123	101
Assets		4,679		4,286
Atlantic City Electric Company [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		1	1
Corporate and Other [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenues		491	480
Depreciation and Amortization		17	21
Operating Expenses		492	481
Interest expense, net		79	72
Income (Loss) before income taxes		(80)	(69)
Income taxes		116	(8)
Net income (loss)		(196)	(61)
Capital expenditures		58	34
Assets		8,788		9,005
Corporate and Other [Member] | Corporate, Non-Segment [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenues		95	93
Depreciation and Amortization		8	9
Operating Expenses		97	93
Interest expense, net		3	3
Income (Loss) before income taxes		(4)	(4)
Income taxes		(3)	(2)
Net income (loss)		(1)	(2)
Capital expenditures		1	0
Assets		5,020		$ 5,079
Corporate and Other [Member] | Corporate, Non-Segment [Member] | Pepco Holdings LLC [Member] | Revision of Prior Period, Adjustment [Member]
Segment Reporting Information [Line Items]
Income (Loss) before income taxes			110
Corporate and Other [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		487	479
Corporate and Other [Member] | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties		95	92
Competitive businesses electric revenues [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		3,894	3,426
Competitive businesses electric revenues [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		(293)	(326)
Competitive businesses electric revenues [Member] | Exelon Generation Co L L C [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		4,187	3,752
Competitive businesses electric revenues [Member] | Commonwealth Edison Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Competitive businesses electric revenues [Member] | PECO Energy Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Competitive businesses electric revenues [Member] | Baltimore Gas and Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Competitive businesses electric revenues [Member] | Pepco Holdings LLC [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Competitive businesses electric revenues [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Competitive businesses natural gas revenues Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		1,326	669
Competitive businesses natural gas revenues Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax			(3)
Competitive businesses natural gas revenues Member] | Exelon Generation Co L L C [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		1,326	672
Competitive businesses natural gas revenues Member] | Commonwealth Edison Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Competitive businesses natural gas revenues Member] | PECO Energy Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Competitive businesses natural gas revenues Member] | Baltimore Gas and Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Competitive businesses natural gas revenues Member] | Pepco Holdings LLC [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Competitive businesses natural gas revenues Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Competitive businesses other revenues [Member]
Segment Reporting Information [Line Items]
Competitive businesses other revenues		45	308
Competitive businesses other revenues [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Competitive businesses other revenues		(1)	(1)
Competitive businesses other revenues [Member] | Exelon Generation Co L L C [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Competitive businesses other revenues		46	309
Competitive businesses other revenues [Member] | Commonwealth Edison Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Competitive businesses other revenues		0	0
Competitive businesses other revenues [Member] | PECO Energy Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Competitive businesses other revenues		0	0
Competitive businesses other revenues [Member] | Baltimore Gas and Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Competitive businesses other revenues		0	0
Competitive businesses other revenues [Member] | Pepco Holdings LLC [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Competitive businesses other revenues		0	0
Competitive businesses other revenues [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Competitive businesses other revenues		0	0
Rate-regulated electric revenues [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		3,988	3,748
Rate-regulated electric revenues [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		1,124	1,086
Rate-regulated electric revenues [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		(10)	(12)
Rate-regulated electric revenues [Member] | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		(4)	(2)
Rate-regulated electric revenues [Member] | Exelon Generation Co L L C [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Rate-regulated electric revenues [Member] | Commonwealth Edison Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		1,535	1,439
Rate-regulated electric revenues [Member] | PECO Energy Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		661	604
Rate-regulated electric revenues [Member] | Baltimore Gas and Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		632	613
Rate-regulated electric revenues [Member] | Pepco Holdings LLC [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		1,170	1,104
Rate-regulated electric revenues [Member] | Potomac Electric Power Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		553	544
Rate-regulated electric revenues [Member] | Delmarva Power and Light Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		311	286
Rate-regulated electric revenues [Member] | Atlantic City Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		310	276
Rate-regulated electric revenues [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Rate-regulated electric revenues [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Rate-regulated natural gas revenues [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		637	595
Rate-regulated natural gas revenues [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		71	64
Rate-regulated natural gas revenues [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		(4)	(2)
Rate-regulated natural gas revenues [Member] | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Rate-regulated natural gas revenues [Member] | Exelon Generation Co L L C [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Rate-regulated natural gas revenues [Member] | Commonwealth Edison Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Rate-regulated natural gas revenues [Member] | PECO Energy Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		228	209
Rate-regulated natural gas revenues [Member] | Baltimore Gas and Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		342	324
Rate-regulated natural gas revenues [Member] | Pepco Holdings LLC [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		71	64
Rate-regulated natural gas revenues [Member] | Potomac Electric Power Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Rate-regulated natural gas revenues [Member] | Delmarva Power and Light Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		71	64
Rate-regulated natural gas revenues [Member] | Atlantic City Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Rate-regulated natural gas revenues [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Rate-regulated natural gas revenues [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Shared service and other revenues [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	1
Shared service and other revenues [Member] | Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		(494)	(482)
Shared service and other revenues [Member] | Intersegment Eliminations [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		(92)	(90)
Shared service and other revenues [Member] | Exelon Generation Co L L C [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Shared service and other revenues [Member] | Commonwealth Edison Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Shared service and other revenues [Member] | PECO Energy Co [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Shared service and other revenues [Member] | Baltimore Gas and Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Shared service and other revenues [Member] | Pepco Holdings LLC [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		3	3
Shared service and other revenues [Member] | Potomac Electric Power Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Shared service and other revenues [Member] | Delmarva Power and Light Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Shared service and other revenues [Member] | Atlantic City Electric Company [Member] | Operating Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		0	0
Shared service and other revenues [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		491	480
Shared service and other revenues [Member] | Corporate and Other [Member] | Corporate, Non-Segment [Member] | Pepco Holdings LLC [Member]
Segment Reporting Information [Line Items]
Revenue from Contract with Customer, Including Assessed Tax		$ 95	$ 93

[1] Exelon’s consolidated assets include $9,985 million and $10,200 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,578 million and $3,598 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 16 — Variable Interest Entities for additional information.

[2] Generation’s consolidated assets include $9,967 million and $10,182 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,557 million and $3,572 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 16 — Variable Interest Entities for additional information.

[3] PHI’s consolidated total assets include $18 million at both March 31, 2021 and December 31, 2020 of PHI's consolidated VIE that can only be used to settle the liabilities of the VIE. PHI’s consolidated total liabilities include $21 million and $26 million at March 31, 2021 and December 31, 2020, respectively, of PHI's consolidated VIE for which the VIE creditors do not have recourse to PHI. See Note 16 — Variable Interest Entities for additional information.

XML

Segment Information - Generation Total Revenues (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Segment Reporting Information [Line Items]
Revenues	$ 9,890	$ 8,747
Revenue from Related Parties	0	1
Generation Mid Atlantic [Member]
Segment Reporting Information [Line Items]
Revenues	1,165	1,174
Generation Midwest [Member]
Segment Reporting Information [Line Items]
Revenues	998	1,002
Generation New York [Member]
Segment Reporting Information [Line Items]
Revenues	337	314
Generation ERCOT [Member]
Segment Reporting Information [Line Items]
Revenues	257	190
Generation Other Regions [Member]
Segment Reporting Information [Line Items]
Revenues	1,430	1,072
Generation Reportable Segments Total [Member]
Segment Reporting Information [Line Items]
Revenues	4,187	3,752
Generation Natural Gas [Member]
Segment Reporting Information [Line Items]
Revenues	1,326	672
Generation All Other Segments [Member]
Segment Reporting Information [Line Items]
Revenues	46	309
Unrealized Gain (Loss) on Securities	(84)	179
Generation Total Consolidated Group [Member]
Segment Reporting Information [Line Items]
Revenues	5,559	4,733
Operating Segment [Member] | Generation Mid Atlantic [Member]
Segment Reporting Information [Line Items]
Revenues	1,160	1,168
Operating Segment [Member] | Generation Midwest [Member]
Segment Reporting Information [Line Items]
Revenues	998	1,008
Operating Segment [Member] | Generation New York [Member]
Segment Reporting Information [Line Items]
Revenues	337	314
Operating Segment [Member] | Generation ERCOT [Member]
Segment Reporting Information [Line Items]
Revenues	252	183
Operating Segment [Member] | Generation Other Regions [Member]
Segment Reporting Information [Line Items]
Revenues	1,440	1,079
Operating Segment [Member] | Generation Reportable Segments Total [Member]
Segment Reporting Information [Line Items]
Revenues	4,187	3,752
Operating Segment [Member] | Generation Natural Gas [Member]
Segment Reporting Information [Line Items]
Revenues	1,326	672
Operating Segment [Member] | Generation All Other Segments [Member]
Segment Reporting Information [Line Items]
Unrealized Gain (Loss) on Securities	175	132
Operating Segment [Member] | Generation Total Consolidated Group [Member]
Segment Reporting Information [Line Items]
Revenues	5,559	4,733
Corporate, Non-Segment [Member] | Generation All Other Segments [Member]
Segment Reporting Information [Line Items]
Revenues	46	309
Intersegment Eliminations [Member]
Segment Reporting Information [Line Items]
Revenues	(802)	(826)
Revenue from Related Parties	(799)	(824)
Intersegment Eliminations [Member] | Generation Mid Atlantic [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	5	6
Intersegment Eliminations [Member] | Generation Midwest [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	0	(6)
Intersegment Eliminations [Member] | Generation New York [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	0	0
Intersegment Eliminations [Member] | Generation ERCOT [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	5	7
Intersegment Eliminations [Member] | Generation Other Regions [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	(10)	(7)
Intersegment Eliminations [Member] | Generation Reportable Segments Total [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	0	0
Intersegment Eliminations [Member] | Generation Natural Gas [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	0	0
Intersegment Eliminations [Member] | Generation All Other Segments [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	0	0
Intersegment Eliminations [Member] | Generation Total Consolidated Group [Member]
Segment Reporting Information [Line Items]
Revenue from Related Parties	0	0
Revenue from Contract with Customer [Member] | Operating Segment [Member] | Generation Mid Atlantic [Member]
Segment Reporting Information [Line Items]
Revenues	1,174	1,264
Revenue from Contract with Customer [Member] | Operating Segment [Member] | Generation Midwest [Member]
Segment Reporting Information [Line Items]
Revenues	1,009	944
Revenue from Contract with Customer [Member] | Operating Segment [Member] | Generation New York [Member]
Segment Reporting Information [Line Items]
Revenues	382	335
Revenue from Contract with Customer [Member] | Operating Segment [Member] | Generation ERCOT [Member]
Segment Reporting Information [Line Items]
Revenues	353	155
Revenue from Contract with Customer [Member] | Operating Segment [Member] | Generation Other Regions [Member]
Segment Reporting Information [Line Items]
Revenues	1,172	1,007
Revenue from Contract with Customer [Member] | Operating Segment [Member] | Generation Reportable Segments Total [Member]
Segment Reporting Information [Line Items]
Revenues	4,090	3,705
Revenue from Contract with Customer [Member] | Operating Segment [Member] | Generation Natural Gas [Member]
Segment Reporting Information [Line Items]
Revenues	864	503
Revenue from Contract with Customer [Member] | Operating Segment [Member] | Generation Total Consolidated Group [Member]
Segment Reporting Information [Line Items]
Revenues	5,043	4,307
Revenue from Contract with Customer [Member] | Corporate, Non-Segment [Member] | Generation All Other Segments [Member]
Segment Reporting Information [Line Items]
Revenues	89	99
Other [Member] | Operating Segment [Member] | Generation Mid Atlantic [Member]
Segment Reporting Information [Line Items]
Revenues	(14)	(96)
Other [Member] | Operating Segment [Member] | Generation Midwest [Member]
Segment Reporting Information [Line Items]
Revenues	(11)	64
Other [Member] | Operating Segment [Member] | Generation New York [Member]
Segment Reporting Information [Line Items]
Revenues	(45)	(21)
Other [Member] | Operating Segment [Member] | Generation ERCOT [Member]
Segment Reporting Information [Line Items]
Revenues	(101)	28
Other [Member] | Operating Segment [Member] | Generation Other Regions [Member]
Segment Reporting Information [Line Items]
Revenues	268	72
Other [Member] | Operating Segment [Member] | Generation Reportable Segments Total [Member]
Segment Reporting Information [Line Items]
Revenues	97	47
Other [Member] | Operating Segment [Member] | Generation Natural Gas [Member]
Segment Reporting Information [Line Items]
Revenues	462	169
Other [Member] | Operating Segment [Member] | Generation Total Consolidated Group [Member]
Segment Reporting Information [Line Items]
Revenues	516	426
Other [Member] | Corporate, Non-Segment [Member] | Generation All Other Segments [Member]
Segment Reporting Information [Line Items]
Revenues	$ (43)	$ 210

XML

Segment Information - Generation Total Revenues Net of Purchased Power and Fuel Expense (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Generation Mid Atlantic [Member]
Segment Reporting Information [Line Items]
Revenue Net of Purchase Power And Fuel	$ 567	$ 567
Generation Midwest [Member]
Segment Reporting Information [Line Items]
Revenue Net of Purchase Power And Fuel	702	727
Generation New York [Member]
Segment Reporting Information [Line Items]
Revenue Net of Purchase Power And Fuel	242	193
Generation ERCOT [Member]
Segment Reporting Information [Line Items]
Revenue Net of Purchase Power And Fuel	(1,184)	80
Generation Other Regions [Member]
Segment Reporting Information [Line Items]
Revenue Net of Purchase Power And Fuel	217	158
Generation Reportable Segments Total [Member]
Segment Reporting Information [Line Items]
Revenue Net of Purchase Power And Fuel	544	1,725
Generation All Other Segments [Member]
Segment Reporting Information [Line Items]
Revenue Net of Purchase Power And Fuel	405	304
Unrealized Gain (Loss) on Securities	(84)	179
Generation Total Consolidated Group [Member]
Segment Reporting Information [Line Items]
Revenue Net of Purchase Power And Fuel	949	2,029
Operating Segment [Member] | Generation Mid Atlantic [Member]
Segment Reporting Information [Line Items]
RNF from external customers	562	559
Operating Segment [Member] | Generation Midwest [Member]
Segment Reporting Information [Line Items]
RNF from external customers	702	732
Operating Segment [Member] | Generation New York [Member]
Segment Reporting Information [Line Items]
RNF from external customers	240	189
Operating Segment [Member] | Generation ERCOT [Member]
Segment Reporting Information [Line Items]
RNF from external customers	(1,036)	76
Operating Segment [Member] | Generation Other Regions [Member]
Segment Reporting Information [Line Items]
RNF from external customers	250	177
Operating Segment [Member] | Generation Reportable Segments Total [Member]
Segment Reporting Information [Line Items]
RNF from external customers	718	1,733
Operating Segment [Member] | Generation All Other Segments [Member]
Segment Reporting Information [Line Items]
RNF from external customers	231	296
Unrealized Gain (Loss) on Securities	175	132
Accelerated nuclear fuel amortization	54
Operating Segment [Member] | Generation Total Consolidated Group [Member]
Segment Reporting Information [Line Items]
RNF from external customers	949	2,029
Intersegment Eliminations [Member] | Generation Mid Atlantic [Member]
Segment Reporting Information [Line Items]
Intersegment Revenue Net Of Purchase Power And Fuel	5	8
Intersegment Eliminations [Member] | Generation Midwest [Member]
Segment Reporting Information [Line Items]
Intersegment Revenue Net Of Purchase Power And Fuel	0	(5)
Intersegment Eliminations [Member] | Generation New York [Member]
Segment Reporting Information [Line Items]
Intersegment Revenue Net Of Purchase Power And Fuel	2	4
Intersegment Eliminations [Member] | Generation ERCOT [Member]
Segment Reporting Information [Line Items]
Intersegment Revenue Net Of Purchase Power And Fuel	(148)	4
Intersegment Eliminations [Member] | Generation Other Regions [Member]
Segment Reporting Information [Line Items]
Intersegment Revenue Net Of Purchase Power And Fuel	(33)	(19)
Intersegment Eliminations [Member] | Generation Reportable Segments Total [Member]
Segment Reporting Information [Line Items]
Intersegment Revenue Net Of Purchase Power And Fuel	(174)	(8)
Intersegment Eliminations [Member] | Generation All Other Segments [Member]
Segment Reporting Information [Line Items]
Intersegment Revenue Net Of Purchase Power And Fuel	174	8
Intersegment Eliminations [Member] | Generation Total Consolidated Group [Member]
Segment Reporting Information [Line Items]
Intersegment Revenue Net Of Purchase Power And Fuel	$ 0	$ 0

XML

Segment Information - Electric and Gas Revenue by Customer Class (Details) - USD ($)	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Revenue, Major Customer [Line Items]
Revenues	$ 9,890,000,000	$ 8,747,000,000
Revenue from Related Parties	0	1,000,000
Commonwealth Edison Co [Member]
Revenue, Major Customer [Line Items]
Revenues	1,535,000,000	1,439,000,000
Revenue from Related Parties	6,000,000	5,000,000
Commonwealth Edison Co [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	54,000,000	12,000,000
Commonwealth Edison Co [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenues	1,473,000,000	1,421,000,000
Commonwealth Edison Co [Member] | Other Regulated Revenue [Member]
Revenue, Major Customer [Line Items]
Revenues	62,000,000	18,000,000
PECO Energy Co [Member]
Revenue, Major Customer [Line Items]
Revenues	889,000,000	813,000,000
Revenue from Related Parties	2,000,000	2,000,000
PECO Energy Co [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	10,000,000	2,000,000
PECO Energy Co [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenues	879,000,000	807,000,000
PECO Energy Co [Member] | Other Regulated Revenue [Member]
Revenue, Major Customer [Line Items]
Revenues	10,000,000	6,000,000
PECO Energy Co [Member] | Rate-Regulated Electric Revenues [Member]
Revenue, Major Customer [Line Items]
Revenue from Related Parties	1,000,000	2,000,000
PECO Energy Co [Member] | Rate-Regulated Natural Gas Revenues [Member]
Revenue, Major Customer [Line Items]
Revenue from Related Parties	1
Baltimore Gas and Electric Company [Member]
Revenue, Major Customer [Line Items]
Revenues	974,000,000	937,000,000
Revenue from Related Parties	6,000,000	6,000,000
Baltimore Gas and Electric Company [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	18,000,000	36,000,000
Baltimore Gas and Electric Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenues	956,000,000	895,000,000
Baltimore Gas and Electric Company [Member] | Other Regulated Revenue [Member]
Revenue, Major Customer [Line Items]
Revenues	18,000,000	42,000,000
Baltimore Gas and Electric Company [Member] | Rate-Regulated Electric Revenues [Member]
Revenue, Major Customer [Line Items]
Revenue from Related Parties	2,000,000	6,000,000
Baltimore Gas and Electric Company [Member] | Rate-Regulated Natural Gas Revenues [Member]
Revenue, Major Customer [Line Items]
Revenue from Related Parties	4,000,000	3,000,000
Pepco Holdings LLC [Member]
Revenue, Major Customer [Line Items]
Revenues	1,244,000,000	1,171,000,000
Revenue from Related Parties	3,000,000	3,000,000
Pepco Holdings LLC [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	46,000,000	18,000,000
Pepco Holdings LLC [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenues	1,198,000,000	1,150,000,000
Pepco Holdings LLC [Member] | Other Regulated Revenue [Member]
Revenue, Major Customer [Line Items]
Revenues	46,000,000	21,000,000
Potomac Electric Power Company [Member]
Revenue, Major Customer [Line Items]
Revenues	553,000,000	544,000,000
Revenue from Related Parties	1,000,000	1,000,000
Potomac Electric Power Company [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	26,000,000	15,000,000
Potomac Electric Power Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenues	527,000,000	528,000,000
Potomac Electric Power Company [Member] | Other Regulated Revenue [Member]
Revenue, Major Customer [Line Items]
Revenues	26,000,000	16,000,000
Delmarva Power and Light Company [Member]
Revenue, Major Customer [Line Items]
Revenues	382,000,000	350,000,000
Revenue from Related Parties	2,000,000	2,000,000
Delmarva Power and Light Company [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	9,000,000	1,000,000
Delmarva Power and Light Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenues	373,000,000	348,000,000
Delmarva Power and Light Company [Member] | Other Regulated Revenue [Member]
Revenue, Major Customer [Line Items]
Revenues	9,000,000	2,000,000
Atlantic City Electric Company [Member]
Revenue, Major Customer [Line Items]
Revenues	310,000,000	276,000,000
Revenue from Related Parties	1,000,000	1,000,000
Atlantic City Electric Company [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	11,000,000	1,000,000
Atlantic City Electric Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenues	299,000,000	274,000,000
Atlantic City Electric Company [Member] | Other Regulated Revenue [Member]
Revenue, Major Customer [Line Items]
Revenues	11,000,000	2,000,000
Rate-regulated electric revenues [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	3,988,000,000	3,748,000,000
Rate-regulated electric revenues [Member] | Commonwealth Edison Co [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	1,475,000,000	1,422,000,000
Rate-regulated electric revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	1,473,000,000	1,421,000,000
Rate-regulated electric revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	8,000,000	6,000,000
Rate-regulated electric revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	741,000,000	701,000,000
Rate-regulated electric revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	367,000,000	362,000,000
Rate-regulated electric revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	134,000,000	134,000,000
Rate-regulated electric revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	11,000,000	13,000,000
Rate-regulated electric revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	220,000,000	211,000,000
Rate-regulated electric revenues [Member] | PECO Energy Co [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	649,000,000	600,000,000
Rate-regulated electric revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	651,000,000	599,000,000
Rate-regulated electric revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	3,000,000
Rate-regulated electric revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	433,000,000	382,000,000
Rate-regulated electric revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	100,000,000	99,000,000
Rate-regulated electric revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	57,000,000	53,000,000
Rate-regulated electric revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	9,000,000	7,000,000
Rate-regulated electric revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	52,000,000	58,000,000
Rate-regulated electric revenues [Member] | Baltimore Gas and Electric Company [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	620,000,000	595,000,000
Rate-regulated electric revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	620,000,000	595,000,000
Rate-regulated electric revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	3,000,000
Rate-regulated electric revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	362,000,000	339,000,000
Rate-regulated electric revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	69,000,000	67,000,000
Rate-regulated electric revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	105,000,000	103,000,000
Rate-regulated electric revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	7,000,000	7,000,000
Rate-regulated electric revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	77,000,000	79,000,000
Rate-regulated electric revenues [Member] | Pepco Holdings LLC [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	1,124,000,000	1,086,000,000
Rate-regulated electric revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	1,127,000,000	1,086,000,000
Rate-regulated electric revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	3,000,000
Rate-regulated electric revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	605,000,000	534,000,000
Rate-regulated electric revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	118,000,000	115,000,000
Rate-regulated electric revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	248,000,000	253,000,000
Rate-regulated electric revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	13,000,000	15,000,000
Rate-regulated electric revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	143,000,000	169,000,000
Rate-regulated electric revenues [Member] | Potomac Electric Power Company [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	526,000,000	528,000,000
Rate-regulated electric revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	527,000,000	528,000,000
Rate-regulated electric revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	1,000,000
Rate-regulated electric revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	253,000,000	236,000,000
Rate-regulated electric revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	33,000,000	35,000,000
Rate-regulated electric revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	184,000,000	188,000,000
Rate-regulated electric revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	6,000,000	9,000,000
Rate-regulated electric revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	51,000,000	60,000,000
Rate-regulated electric revenues [Member] | Delmarva Power and Light Company [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	300,000,000	283,000,000
Rate-regulated electric revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	302,000,000	284,000,000
Rate-regulated electric revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	1,000,000
Rate-regulated electric revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	190,000,000	161,000,000
Rate-regulated electric revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	46,000,000	43,000,000
Rate-regulated electric revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	21,000,000	23,000,000
Rate-regulated electric revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	4,000,000	3,000,000
Rate-regulated electric revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	41,000,000	54,000,000
Rate-regulated electric revenues [Member] | Atlantic City Electric Company [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	298,000,000	274,000,000
Rate-regulated electric revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	299,000,000	274,000,000
Rate-regulated electric revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	1,000,000
Rate-regulated electric revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	162,000,000	137,000,000
Rate-regulated electric revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	39,000,000	37,000,000
Rate-regulated electric revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	43,000,000	42,000,000
Rate-regulated electric revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Public Authorities & Electric Railroads [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	3,000,000	3,000,000
Rate-regulated electric revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	52,000,000	55,000,000
Rate-regulated natural gas revenues [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	637,000,000	595,000,000
Rate-regulated natural gas revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Transportation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Commonwealth Edison Co [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | PECO Energy Co [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	228,000,000	209,000,000
Rate-regulated natural gas revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	228,000,000	208,000,000
Rate-regulated natural gas revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	1,000,000
Rate-regulated natural gas revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	160,000,000	150,000,000
Rate-regulated natural gas revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	59,000,000	51,000,000
Rate-regulated natural gas revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Transportation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	7,000,000	6,000,000
Rate-regulated natural gas revenues [Member] | PECO Energy Co [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	2,000,000	1,000,000
Rate-regulated natural gas revenues [Member] | Baltimore Gas and Electric Company [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	330,000,000	300,000,000
Rate-regulated natural gas revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	336,000,000	300,000,000
Rate-regulated natural gas revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	3,000,000
Rate-regulated natural gas revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	216,000,000	206,000,000
Rate-regulated natural gas revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	35,000,000	34,000,000
Rate-regulated natural gas revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	54,000,000	51,000,000
Rate-regulated natural gas revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Transportation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Baltimore Gas and Electric Company [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	31,000,000	9,000,000
Rate-regulated natural gas revenues [Member] | Pepco Holdings LLC [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	71,000,000	64,000,000
Rate-regulated natural gas revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	71,000,000	64,000,000
Rate-regulated natural gas revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	46,000,000	40,000,000
Rate-regulated natural gas revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	18,000,000	17,000,000
Rate-regulated natural gas revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	2,000,000	1,000,000
Rate-regulated natural gas revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Transportation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	4,000,000	4,000,000
Rate-regulated natural gas revenues [Member] | Pepco Holdings LLC [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	1,000,000	2,000,000
Rate-regulated natural gas revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Transportation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Potomac Electric Power Company [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Delmarva Power and Light Company [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	71,000,000	64,000,000
Rate-regulated natural gas revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	71,000,000	64,000,000
Rate-regulated natural gas revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	46,000,000	40,000,000
Rate-regulated natural gas revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	18,000,000	17,000,000
Rate-regulated natural gas revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	2,000,000	1,000,000
Rate-regulated natural gas revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Transportation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	4,000,000	4,000,000
Rate-regulated natural gas revenues [Member] | Delmarva Power and Light Company [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	1,000,000	2,000,000
Rate-regulated natural gas revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Operating Segment [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Residential [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Small Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Large Commercial & Industrial [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Transportation [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	0	0
Rate-regulated natural gas revenues [Member] | Atlantic City Electric Company [Member] | Regulated Operation [Member] | Other [Member]
Revenue, Major Customer [Line Items]
Revenue from Contract with Customer, Including Assessed Tax	$ 0	$ 0

XML

Accounts Receivable - Narrative (Details) - Sale of accounts receivable [Member] - USD ($) $ in Millions	Mar. 31, 2021	Feb. 17, 2021	Dec. 31, 2020	Apr. 08, 2020
Accounts, Notes, Loans and Financing Receivable [Line Items]
Derecognized receivables transferred at fair value	$ 1,301		$ 1,139	$ 1,200
Cash proceeds received	900	$ 250	500	500
DPP consideration	401		639	650
March 29, 2024
Accounts, Notes, Loans and Financing Receivable [Line Items]
Line of Credit Facility, Maximum borrowing capacity	900
Cash proceeds received	150
April 7, 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Line of Credit Facility, Maximum borrowing capacity	750
Exelon Generation Co L L C [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Derecognized receivables transferred at fair value	1,301		1,139	1,200
Cash proceeds received	900	$ 250	500	500
DPP consideration	401		$ 639	$ 650
Exelon Generation Co L L C [Member] | March 29, 2024
Accounts, Notes, Loans and Financing Receivable [Line Items]
Line of Credit Facility, Maximum borrowing capacity	900
Cash proceeds received	150
Exelon Generation Co L L C [Member] | April 7, 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Line of Credit Facility, Maximum borrowing capacity	$ 750

XML

Accounts Receivable - Allowance for Credit Losses Rollforward (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Accounts Receivable, Allowance for Credit Loss [Line Items]
Current period provision for expected credit losses	$ (85)	$ (45)
Exelon Generation Co L L C [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Current period provision for expected credit losses	(34)	(4)
Commonwealth Edison Co [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Current period provision for expected credit losses	(13)	(7)
PECO Energy Co [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Current period provision for expected credit losses	(24)	(17)
Baltimore Gas and Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Current period provision for expected credit losses	(4)	(7)
Pepco Holdings LLC [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Current period provision for expected credit losses	(10)	(10)
Potomac Electric Power Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Current period provision for expected credit losses	(5)	(4)
Delmarva Power and Light Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Current period provision for expected credit losses	(4)	(3)
Atlantic City Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Current period provision for expected credit losses	(1)	(3)
Customer accounts receivable
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	366	243
Current period provision for expected credit losses	104	55
Writeoffs, net of recoveries	28	20
Ending balance	442	278
Customer accounts receivable | Exelon Generation Co L L C [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	32	80
Current period provision for expected credit losses	34	4
Writeoffs, net of recoveries	1	3
Ending balance	65	81
Customer accounts receivable | Commonwealth Edison Co [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	97	59
Current period provision for expected credit losses	21	18
Writeoffs, net of recoveries	15	6
Ending balance	103	71
Customer accounts receivable | PECO Energy Co [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	116	55
Current period provision for expected credit losses	20	18
Writeoffs, net of recoveries	6	7
Ending balance	130	66
Customer accounts receivable | Baltimore Gas and Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	35	12
Current period provision for expected credit losses	9	8
Writeoffs, net of recoveries	1	2
Ending balance	43	18
Customer accounts receivable | Pepco Holdings LLC [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	86	37
Current period provision for expected credit losses	20	7
Writeoffs, net of recoveries	5	2
Ending balance	101	42
Customer accounts receivable | Potomac Electric Power Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	32	13
Current period provision for expected credit losses	11	3
Writeoffs, net of recoveries	2	1
Ending balance	41	15
Customer accounts receivable | Delmarva Power and Light Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	22	11
Current period provision for expected credit losses	6	2
Writeoffs, net of recoveries	3	0
Ending balance	25	13
Customer accounts receivable | Atlantic City Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	32	13
Current period provision for expected credit losses	3	2
Writeoffs, net of recoveries	0	1
Ending balance	35	14
Other receivables
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	71	48
Current period provision for expected credit losses	10	8
Writeoffs, net of recoveries	2	4
Ending balance	79	52
Other receivables | Exelon Generation Co L L C [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	0	0
Current period provision for expected credit losses	0	0
Writeoffs, net of recoveries	0	0
Ending balance	0	0
Other receivables | Commonwealth Edison Co [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	21	20
Current period provision for expected credit losses	1	3
Writeoffs, net of recoveries	0	1
Ending balance	22	22
Other receivables | PECO Energy Co [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	8	7
Current period provision for expected credit losses	4	1
Writeoffs, net of recoveries	1	1
Ending balance	11	7
Other receivables | Baltimore Gas and Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	9	5
Current period provision for expected credit losses	1	2
Writeoffs, net of recoveries	1	2
Ending balance	9	5
Other receivables | Pepco Holdings LLC [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	33	16
Current period provision for expected credit losses	4	2
Writeoffs, net of recoveries	0	0
Ending balance	37	18
Other receivables | Potomac Electric Power Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	13	7
Current period provision for expected credit losses	2	1
Writeoffs, net of recoveries	0	0
Ending balance	15	8
Other receivables | Delmarva Power and Light Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	9	4
Current period provision for expected credit losses	1	0
Writeoffs, net of recoveries	0	0
Ending balance	10	4
Other receivables | Atlantic City Electric Company [Member]
Accounts Receivable, Allowance for Credit Loss [Line Items]
Beginning balance	11	5
Current period provision for expected credit losses	1	1
Writeoffs, net of recoveries	0	0
Ending balance	$ 12	$ 6

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Accounts Receivable - Unbilled Customer Revenue (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	$ 1,178	$ 998
Exelon Generation Co L L C [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	671	258
Commonwealth Edison Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	161	218
PECO Energy Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	102	147
Baltimore Gas and Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	126	197
Pepco Holdings LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	118	178
Potomac Electric Power Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	58	87
Delmarva Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	38	62
Atlantic City Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Unbilled customer revenue	$ 22	$ 29

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Accounts Receivable - Purchases and Sales of Accounts Receivable (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Feb. 17, 2021	Dec. 31, 2020	Apr. 08, 2020
Accounts, Notes, Loans and Financing Receivable [Line Items]
Loss on sale receivables	$ 17
Proceeds from new transfers	1,036
Cash collections received on deferred purchase price and reinvested in the Facility	1,174
Cash collections reinvested in the Facility	2,210
Accounts Receivable, Purchase	1,011	$ 781
Accounts Receivable, Sale	69	507
Exelon Generation Co L L C [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Loss on sale receivables	17
Proceeds from new transfers	1,036
Cash collections received on deferred purchase price and reinvested in the Facility	1,174
Cash collections reinvested in the Facility	2,210
Accounts Receivable, Purchase	0	0
Accounts Receivable, Sale	81	749
Commonwealth Edison Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	266	280
Accounts Receivable, Sale	0	0
PECO Energy Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	290	284
Accounts Receivable, Sale	0	0
Baltimore Gas and Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	199	195
Accounts Receivable, Sale	0	0
Pepco Holdings LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	268	264
Accounts Receivable, Sale	0	0
Potomac Electric Power Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	166	165
Accounts Receivable, Sale	0	0
Delmarva Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	56	53
Accounts Receivable, Sale	0	0
Atlantic City Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Purchase	46	46
Accounts Receivable, Sale	0	0
Exelon Generation Co LLC Affiliate [Member] | Commonwealth Edison Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Related Parties, Purchase	0	34
Exelon Generation Co LLC Affiliate [Member] | PECO Energy Co [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Related Parties, Purchase	0	67
Exelon Generation Co LLC Affiliate [Member] | Baltimore Gas and Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Related Parties, Purchase	12	69
Exelon Generation Co LLC Affiliate [Member] | Pepco Holdings LLC [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Related Parties, Purchase	0	72
Exelon Generation Co LLC Affiliate [Member] | Potomac Electric Power Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Related Parties, Purchase	0	51
Exelon Generation Co LLC Affiliate [Member] | Delmarva Power and Light Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Related Parties, Purchase	0	13
Exelon Generation Co LLC Affiliate [Member] | Atlantic City Electric Company [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Related Parties, Purchase	0	8
Exelon Utility Registrants Affiliates [Member] | Exelon Generation Co L L C [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts Receivable, Related Parties, Sale	12	$ 242
Sale of accounts receivable [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Derecognized receivables transferred at fair value	1,301			$ 1,139	$ 1,200
Cash proceeds received	900		$ 250	500	500
DPP consideration	401			639	650
Transfer of Financial Assets Accounted for as Sales, Additional Transfers	2,375
Sale of accounts receivable [Member] | Exelon Generation Co L L C [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Derecognized receivables transferred at fair value	1,301			1,139	1,200
Cash proceeds received	900		$ 250	500	500
DPP consideration	401			$ 639	$ 650
Transfer of Financial Assets Accounted for as Sales, Additional Transfers	2,375
Sale of Accounts Receivable_Three Months Ended Q1 2021
Accounts, Notes, Loans and Financing Receivable [Line Items]
Cash proceeds received	400
Sale of Accounts Receivable_Three Months Ended Q1 2021 | Exelon Generation Co L L C [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Cash proceeds received	$ 400

XML

Early Plant Retirements - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Cost, Depreciation and Amortization	$ 1,697	$ 1,021
Exelon Generation Co L L C [Member]
Property, Plant and Equipment [Line Items]
Cost, Depreciation and Amortization	$ 940	$ 304
Salem [Member] | Nuclear Plant [Member] | Exelon Generation Co L L C [Member]
Property, Plant and Equipment [Line Items]
Ownership interest	42.59%
Midwest Asset Group [Member]
Property, Plant and Equipment [Line Items]
Cost, Depreciation and Amortization	$ 20
Generation New England [Member] | Exelon Generation Co L L C [Member]
Property, Plant and Equipment [Line Items]
Cost, Depreciation and Amortization	20
Facility Closing [Member] | Midwest Asset Group [Member]
Property, Plant and Equipment [Line Items]
Severance Liability	81
Severance Costs			$ 81
Facility Closing [Member] | Midwest Asset Group [Member] | Exelon Generation Co L L C [Member]
Property, Plant and Equipment [Line Items]
Severance Liability	$ 81
Severance Costs			$ 81

XML

Early Plant Retirements - Pretax Expense (Details) - Facility Closing [Member] - Byron Dresden $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($)
Accelerated depreciation	$ 620
Accelerated nuclear fuel amortization	54
Operating and maintenance	2
Asset Retirement Obligation Contractual Offset	(226)
Restructuring and Related Cost, Incurred Cost	450
Exelon Generation Co L L C [Member]
Accelerated depreciation	620
Accelerated nuclear fuel amortization	54
Operating and maintenance	2
Asset Retirement Obligation Contractual Offset	(226)
Restructuring and Related Cost, Incurred Cost	$ 450

XML

Early Plant Retirements - Implications of Potential Early Plant Retirement on Balance Sheet (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Implications of Potential Early Plant Retirement [Line Items]
Materials and supplies inventory, net	$ 1,427	$ 1,425
Property, plant and equipment, net	82,588	82,584
Braidwood [Member] | Facility Closing [Member]
Implications of Potential Early Plant Retirement [Line Items]
Materials and supplies inventory, net	83
Nuclear fuel inventory, net	165
Property, plant and equipment, net	1,379
Construction work in progress	33
Asset retirement obligation	(577)
LaSalle [Member] | Facility Closing [Member]
Implications of Potential Early Plant Retirement [Line Items]
Inventory, Raw Materials, Net of Reserves	103
Nuclear fuel inventory, net	264
Property, plant and equipment, net	1,566
Construction work in progress	70
Asset retirement obligation	(964)
Braidwood LaSalle [Member] | Facility Closing [Member]
Implications of Potential Early Plant Retirement [Line Items]
Materials and supplies inventory, net	186
Nuclear fuel inventory, net	429
Property, plant and equipment, net	2,945
Construction work in progress	103
Asset retirement obligation	(1,541)
Exelon Generation Co L L C [Member]
Implications of Potential Early Plant Retirement [Line Items]
Materials and supplies inventory, net	973	978
Property, plant and equipment, net	21,311	$ 22,214
Exelon Generation Co L L C [Member] | Braidwood [Member] | Facility Closing [Member]
Implications of Potential Early Plant Retirement [Line Items]
Materials and supplies inventory, net	83
Nuclear fuel inventory, net	165
Property, plant and equipment, net	1,379
Construction work in progress	33
Asset retirement obligation	(577)
Exelon Generation Co L L C [Member] | LaSalle [Member] | Facility Closing [Member]
Implications of Potential Early Plant Retirement [Line Items]
Inventory, Raw Materials, Net of Reserves	103
Nuclear fuel inventory, net	264
Property, plant and equipment, net	1,566
Construction work in progress	70
Asset retirement obligation	(964)
Exelon Generation Co L L C [Member] | Braidwood LaSalle [Member] | Facility Closing [Member]
Implications of Potential Early Plant Retirement [Line Items]
Materials and supplies inventory, net	186
Nuclear fuel inventory, net	429
Property, plant and equipment, net	2,945
Construction work in progress	103
Asset retirement obligation	$ (1,541)

XML

Nuclear Decommissioning - Narrative (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Nuclear Decommissioning Additional Narrative Information [Line Items]
Nuclear decommissioning trust funds	$ 14,688	$ 14,464
Exelon Generation Co L L C [Member]
Nuclear Decommissioning Additional Narrative Information [Line Items]
Nuclear decommissioning trust funds	14,688	14,464
Assets, Total [Member]
Nuclear Decommissioning Additional Narrative Information [Line Items]
Nuclear decommissioning trust funds	14,927	14,599
Assets, Total [Member] | Exelon Generation Co L L C [Member]
Nuclear Decommissioning Additional Narrative Information [Line Items]
Nuclear decommissioning trust funds	14,927	14,599
Other Current Assets [Member]
Nuclear Decommissioning Additional Narrative Information [Line Items]
Nuclear decommissioning trust funds	239	134
Other Current Assets [Member] | Exelon Generation Co L L C [Member]
Nuclear Decommissioning Additional Narrative Information [Line Items]
Nuclear decommissioning trust funds	$ 239	$ 134

XML

Nuclear Decommissioning - Rollforward of Nuclear Decommissioning ARO (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020	Dec. 31, 2020
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Accretion expense	$ 127	$ 124
Exelon Generation Co L L C [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Accretion expense	127	$ 124
Nuclear Decommissioning [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO beginning balance	11,922
Accretion expense	124
Costs incurred related to decommissioning plants	(20)
ARO ending balance	12,026
Current portion of ARO	80		$ 80
Nuclear Decommissioning [Member] | Exelon Generation Co L L C [Member]
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
ARO beginning balance	11,922
Accretion expense	124
Costs incurred related to decommissioning plants	(20)
ARO ending balance	12,026
Current portion of ARO	$ 80		$ 80

XML

Asset Impairments - Narrative (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Property, Plant and Equipment [Line Items]
Impairment of Long-Lived Assets Held-for-use	$ 1	$ 8
Net income (loss) attributable to noncontrolling interests	25	(206)
Deferred income taxes and amortization of investment tax credits	(142)	(245)
Exelon Generation Co L L C [Member]
Property, Plant and Equipment [Line Items]
Impairment of Long-Lived Assets Held-for-use	1	8
Net income (loss) attributable to noncontrolling interests	24	(206)
Deferred income taxes and amortization of investment tax credits	(123)	$ (329)
Antelope Valley [Member]
Property, Plant and Equipment [Line Items]
Impairment of Long-Lived Assets Held-for-use	0
Antelope Valley [Member] | Exelon Generation Co L L C [Member]
Property, Plant and Equipment [Line Items]
Impairment of Long-Lived Assets Held-for-use	0
Midwest Asset Group [Member]
Property, Plant and Equipment [Line Items]
Impairment of Long-Lived Assets Held-for-use	0
Midwest Asset Group [Member] | Exelon Generation Co L L C [Member]
Property, Plant and Equipment [Line Items]
Impairment of Long-Lived Assets Held-for-use	$ 0

XML

Income Taxes - Narrative (Details) $ in Millions	Mar. 31, 2021 USD ($)
State and Local Jurisdiction [Member] | Atlantic City Electric Company [Member]
Income Tax Additional Narrative Information [Line Items]
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit	$ 14

XML

Income Taxes - Reconciliation to Effective Tax Rate (Details)	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	14.60%	34.00%
Qualified nuclear decommissioning trust fund income	(18.40%)	(235.80%)
Amortization of investment tax credit, including deferred taxes on basis difference	2.40%	(4.50%)
Plant basis differences	8.80%	(23.00%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	6.70%	(9.90%)
Noncontrolling interests	0.60%	10.60%
Excess deferred tax amortization	27.90%	(71.70%)
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent		(79.10%)
Other	(56.90%)	12.50%
Effective income tax rate	6.70%	(345.90%)
Exelon Generation Co L L C [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	4.40%	0.70%
Qualified nuclear decommissioning trust fund income	(5.50%)	36.40%
Amortization of investment tax credit, including deferred taxes on basis difference	0.60%	0.50%
Plant basis differences	0.00%	0.00%
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	1.80%	1.30%
Noncontrolling interests	0.20%	(1.60%)
Excess deferred tax amortization	0.00%	0.00%
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent		12.20%
Other	(3.60%)	0.60%
Effective income tax rate	18.90%	71.10%
Commonwealth Edison Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	6.80%	8.30%
Qualified nuclear decommissioning trust fund income	0.00%	0.00%
Amortization of investment tax credit, including deferred taxes on basis difference	(0.10%)	(0.20%)
Plant basis differences	(0.60%)	(1.10%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.20%)	(0.20%)
Noncontrolling interests	0.00%	0.00%
Excess deferred tax amortization	(6.90%)	(10.50%)
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent		0.00%
Other	(3.50%)	0.30%
Effective income tax rate	16.50%	17.60%
PECO Energy Co [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	(1.60%)	0.10%
Qualified nuclear decommissioning trust fund income	0.00%	0.00%
Amortization of investment tax credit, including deferred taxes on basis difference	0.00%	0.00%
Plant basis differences	(10.50%)	(8.40%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	0.00%	0.00%
Noncontrolling interests	0.00%	0.00%
Excess deferred tax amortization	(3.20%)	(3.00%)
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent		0.00%
Other	(0.10%)	0.00%
Effective income tax rate	5.60%	9.70%
Baltimore Gas and Electric Company [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	(10.10%)	5.70%
Qualified nuclear decommissioning trust fund income	0.00%	0.00%
Amortization of investment tax credit, including deferred taxes on basis difference	(0.10%)	(0.10%)
Plant basis differences	(1.40%)	(1.20%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.40%)	(0.20%)
Noncontrolling interests	0.00%	0.00%
Excess deferred tax amortization	(15.50%)	(7.30%)
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent		0.00%
Other	(0.10%)	0.60%
Effective income tax rate	(6.60%)	18.50%
Pepco Holdings LLC [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	6.10%	5.80%
Qualified nuclear decommissioning trust fund income	0.00%	0.00%
Amortization of investment tax credit, including deferred taxes on basis difference	(0.10%)	(0.10%)
Plant basis differences	(1.50%)	(1.40%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.20%)	0.00%
Noncontrolling interests	0.00%	0.00%
Excess deferred tax amortization	(19.30%)	(15.50%)
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent		0.00%
Other	(0.10%)	(0.60%)
Effective income tax rate	5.90%	9.20%
Potomac Electric Power Company [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	5.50%	4.70%
Qualified nuclear decommissioning trust fund income	0.00%	0.00%
Amortization of investment tax credit, including deferred taxes on basis difference	0.00%	0.00%
Plant basis differences	(2.10%)	(2.10%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.20%)	0.00%
Noncontrolling interests	0.00%	0.00%
Excess deferred tax amortization	(15.10%)	(14.20%)
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent		0.00%
Other	0.10%	(0.60%)
Effective income tax rate	9.20%	8.80%
Delmarva Power and Light Company [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	6.40%	6.60%
Qualified nuclear decommissioning trust fund income	0.00%	0.00%
Amortization of investment tax credit, including deferred taxes on basis difference	(0.20%)	(0.20%)
Plant basis differences	(0.70%)	(0.70%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.10%)	0.00%
Noncontrolling interests	0.00%	0.00%
Excess deferred tax amortization	(18.50%)	(12.70%)
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent		0.00%
Other	0.30%	(0.50%)
Effective income tax rate	8.20%	13.50%
Atlantic City Electric Company [Member]
Effective Income Tax Rate Reconciliation, Percent [Abstract]
U.S. Federal statutory rate	21.00%	21.00%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	6.90%	6.70%
Qualified nuclear decommissioning trust fund income	0.00%	0.00%
Amortization of investment tax credit, including deferred taxes on basis difference	(0.20%)	(0.20%)
Plant basis differences	(0.90%)	(0.80%)
Effective Income Tax Rate Reconciliation, Tax Credit, Other, Percent	(0.30%)	0.00%
Noncontrolling interests	0.00%	0.00%
Excess deferred tax amortization	(28.70%)	(18.80%)
Effective Income Tax Rate Reconciliation, Tax Settlement, Percent		0.00%
Other	2.20%	(0.80%)
Effective income tax rate	0.00%	7.10%

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Income Taxes - Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Pepco Holdings LLC [Member]
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits	$ 52	$ 52
Atlantic City Electric Company [Member]
Income Tax Contingency [Line Items]
Unrecognized Tax Benefits	$ 15	$ 15

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Retirement Benefits - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Increase (Decrease) in Obligation, Pension Benefits	$ 33
Increase (Decrease) in Obligation, Other Postretirement Benefits	(9)
Accumulated Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), after Tax	1
Defined Benefit Plan Amounts Recognized In Regulatory Assets Before Tax	21
Defined Benefit Plan Amounts Recognized In Regulatory Liabilities Before Tax	$ 1
Pension Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on assets	7.00%
Discount rate	2.58%
Other Postretirement Benefit Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Expected return on assets	6.46%
Discount rate	2.51%

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Retirement Benefits - Calculation of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Amortization of:
Net periodic benefit cost	$ (20)	$ (10)
Pension Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	110	97
Interest cost	161	189
Expected return on assets	(336)	(318)
Amortization of:
Prior service cost (credit)	1	1
Actuarial loss	150	128
Curtailment benefits	0	0
Net periodic benefit cost	86	97
Other Postretirement Benefit Plan, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	21	23
Interest cost	28	38
Expected return on assets	(40)	(41)
Amortization of:
Prior service cost (credit)	(8)	(31)
Actuarial loss	9	12
Curtailment benefits	(1)	0
Net periodic benefit cost	$ 9	$ 1

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Retirement Benefits - Allocated Portion of Pension and Postretirement Benefit Plan Costs (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	$ 95	$ 98
Pension and other post retirement benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	95	98
Exelon Generation Co L L C [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	26	27
Exelon Generation Co L L C [Member] | Pension and other post retirement benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	26	27
Commonwealth Edison Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	32	28
Commonwealth Edison Co [Member] | Pension and other post retirement benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	32	28
PECO Energy Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	2	1
PECO Energy Co [Member] | Pension and other post retirement benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	2	1
Baltimore Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	14	15
Baltimore Gas and Electric Company [Member] | Pension and other post retirement benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	15	16
Pepco Holdings LLC [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	12	17
Pepco Holdings LLC [Member] | Pension and other post retirement benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	12	17
Potomac Electric Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	2	3
Potomac Electric Power Company [Member] | Pension and other post retirement benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	2	3
Delmarva Power and Light Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	1	1
Delmarva Power and Light Company [Member] | Pension and other post retirement benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	1	1
Atlantic City Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	3	3
Atlantic City Electric Company [Member] | Pension and other post retirement benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension and Other Postretirement Benefits Costs	$ 3	$ 3

XML

Retirement Benefits - Defined Contribution Savings Plans (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	$ 33	$ 33
Exelon Generation Co L L C [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	13	13
Commonwealth Edison Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	8	7
PECO Energy Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	3	3
Baltimore Gas and Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	2	2
Pepco Holdings LLC [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	3	3
Potomac Electric Power Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	1	1
Delmarva Power and Light Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Savings Plans Matching Contributions	$ 1	$ 1

XML

Derivative Financial Instruments - Narrative (Details) MWh in Millions, $ in Millions	1 Months Ended	3 Months Ended
	Jun. 30, 2012 MWh	Mar. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Derivative [Line Items]
Derivative, Notional Amount		$ 158	$ 104
Incremental Collateral For Loss Of Investment Grade Credit Rating		1,379	1,432
Exelon Generation Co L L C [Member]
Derivative [Line Items]
Derivative, Notional Amount		158	104
Incremental Collateral For Loss Of Investment Grade Credit Rating		1,379	1,432
Commonwealth Edison Co [Member]
Derivative [Line Items]
Long-term Purchase Commitment, Minimum Energy Volume Required | MWh	1.3
PECO Energy Co [Member]
Derivative [Line Items]
Incremental Collateral For Loss Of Investment Grade Credit Rating		32
Baltimore Gas and Electric Company [Member]
Derivative [Line Items]
Incremental Collateral For Loss Of Investment Grade Credit Rating		48
Delmarva Power and Light Company [Member]
Derivative [Line Items]
Incremental Collateral For Loss Of Investment Grade Credit Rating		$ 12
Minimum [Member] | Exelon Generation Co L L C [Member]
Derivative [Line Items]
Expected Generation Hedged In Next Twelve Months		94.00%
Maximum [Member] | Exelon Generation Co L L C [Member]
Derivative [Line Items]
Expected Generation Hedged In Next Twelve Months		97.00%
Not Designated as Hedging Instrument, Economic Hedge [Member]
Derivative [Line Items]
Derivative, Notional Amount		$ 563	665
Not Designated as Hedging Instrument, Economic Hedge [Member] | Exelon Generation Co L L C [Member]
Derivative [Line Items]
Derivative, Notional Amount		$ 563	$ 665

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Derivative Financial Instruments - Summary of Derivative Fair Value Balances (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Derivative [Line Items]
Mark-to-market derivative assets, current	$ 568	$ 644
Derivative Asset, Noncurrent	491	555
Mark-to-market derivative liabilities, current	(422)	(295)
Mark-to-market derivative liabilities, noncurrent	(453)	(473)
Margin Deposit Assets	148	209
Commodity Contract [Member]
Derivative [Line Items]
Mark-to-market derivative assets, current	569	639
Derivative Asset, Noncurrent	488	554
Total mark-to-market derivative assets	1,057	1,193
Mark-to-market derivative liabilities, current	(418)	(293)
Mark-to-market derivative liabilities, noncurrent	(454)	(472)
Total mark-to-market derivative liabilities	(872)	(765)
Total mark-to-market derivative net assets (liabilities)	185	428
Exelon Generation Co L L C [Member]
Derivative [Line Items]
Mark-to-market derivative assets, current	569	644
Derivative Asset, Noncurrent	491	555
Mark-to-market derivative liabilities, current	(392)	(262)
Mark-to-market derivative liabilities, noncurrent	(190)	(205)
Margin Deposit Assets	148	209
Exelon Generation Co L L C [Member] | Commodity Contract [Member]
Derivative [Line Items]
Mark-to-market derivative assets, current	569	639
Derivative Asset, Noncurrent	488	554
Total mark-to-market derivative assets	1,057	1,193
Mark-to-market derivative liabilities, current	(387)	(260)
Mark-to-market derivative liabilities, noncurrent	(190)	(204)
Total mark-to-market derivative liabilities	(577)	(464)
Total mark-to-market derivative net assets (liabilities)	480	729
Commonwealth Edison Co [Member]
Derivative [Line Items]
Mark-to-market derivative liabilities, current	(31)	(33)
Mark-to-market derivative liabilities, noncurrent	(264)	(268)
Collateral [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member]
Derivative [Line Items]
Mark-to-market derivative assets, current	24	103
Derivative Asset, Noncurrent	45	64
Total mark-to-market derivative assets	69	167
Mark-to-market derivative liabilities, current	49	131
Mark-to-market derivative liabilities, noncurrent	28	118
Total mark-to-market derivative liabilities	77	249
Total mark-to-market derivative net assets (liabilities)	146	416
Netting [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member]
Derivative [Line Items]
Mark-to-market derivative assets, current	(2,049)	(2,261)
Derivative Asset, Noncurrent	(962)	(1,015)
Total mark-to-market derivative assets	(3,011)	(3,276)
Mark-to-market derivative liabilities, current	2,049	2,261
Mark-to-market derivative liabilities, noncurrent	962	1,015
Total mark-to-market derivative liabilities	3,011	3,276
Total mark-to-market derivative net assets (liabilities)	0	0
Not Designated as Hedging Instrument, Economic Hedge [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member]
Derivative [Line Items]
Mark-to-market derivative assets, current	2,566	2,757
Derivative Asset, Noncurrent	1,400	1,501
Total mark-to-market derivative assets	3,966	4,258
Mark-to-market derivative liabilities, current	(2,472)	(2,629)
Mark-to-market derivative liabilities, noncurrent	(1,179)	(1,335)
Total mark-to-market derivative liabilities	(3,651)	(3,964)
Total mark-to-market derivative net assets (liabilities)	315	294
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commonwealth Edison Co [Member] | Commodity Contract [Member]
Derivative [Line Items]
Mark-to-market derivative assets, current	0	0
Derivative Asset, Noncurrent	0	0
Total mark-to-market derivative assets	0	0
Mark-to-market derivative liabilities, current	(31)	(33)
Mark-to-market derivative liabilities, noncurrent	(264)	(268)
Total mark-to-market derivative liabilities	(295)	(301)
Total mark-to-market derivative net assets (liabilities)	(295)	(301)
Not Designated as Hedging Instrument [Member] | Exelon Generation Co L L C [Member] | Commodity Contract [Member]
Derivative [Line Items]
Mark-to-market derivative assets, current	28	40
Derivative Asset, Noncurrent	5	4
Total mark-to-market derivative assets	33	44
Mark-to-market derivative liabilities, current	(13)	(23)
Mark-to-market derivative liabilities, noncurrent	(1)	(2)
Total mark-to-market derivative liabilities	(14)	(25)
Total mark-to-market derivative net assets (liabilities)	$ 19	$ 19

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Derivative Financial Instruments - Summary of Economic Hedges (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Derivative [Line Items]
Unrealized Gain (Loss) on Derivatives	$ 178	$ 132
Exelon Generation Co L L C [Member]
Derivative [Line Items]
Unrealized Gain (Loss) on Derivatives	178	127
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member]
Derivative [Line Items]
Unrealized Gain (Loss) on Derivatives	182	128
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member] | Exelon Generation Co L L C [Member]
Derivative [Line Items]
Unrealized Gain (Loss) on Derivatives	182	128
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member] | Operating Revenue [Member]
Derivative [Line Items]
Unrealized Gain (Loss) on Derivatives	(83)	175
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member] | Operating Revenue [Member] | Exelon Generation Co L L C [Member]
Derivative [Line Items]
Unrealized Gain (Loss) on Derivatives	(83)	175
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member] | Purchased Power And Fuel [Member]
Derivative [Line Items]
Unrealized Gain (Loss) on Derivatives	265	(47)
Not Designated as Hedging Instrument, Economic Hedge [Member] | Commodity Contract [Member] | Purchased Power And Fuel [Member] | Exelon Generation Co L L C [Member]
Derivative [Line Items]
Unrealized Gain (Loss) on Derivatives	$ 265	$ (47)

XML

Derivative Financial Instruments - Summary of Credit Risk Exposure (Details) - Exelon Generation Co L L C [Member] $ in Millions	Mar. 31, 2021 USD ($)
Derivative [Line Items]
Cash Collateral Held	$ 32
Letters Of Credit Held	29
Total Exposure Before Credit Collateral [Member]
Derivative [Line Items]
Investment grade	431
Non-investment grade	43
Internally rated - investment grade	146
Internally rated - non-investment grade	70
Total	690
Credit Collateral [Member]
Derivative [Line Items]
Investment grade	31
Non-investment grade	4
Internally rated - investment grade	1
Internally rated - non-investment grade	25
Total	61
Net Exposure [Member]
Derivative [Line Items]
Investment grade	400
Non-investment grade	39
Internally rated - investment grade	145
Internally rated - non-investment grade	45
Total	629
Investor-owned utilities, marketers and power producers	451
Energy Cooperatives And Municipalities	123
Other	55
Number Of Counterparties Greater Than Ten Percent Of Net Exposure [Member]
Derivative [Line Items]
Investment grade	0
Total	0
Net Exposure Of Counterparties Greater Than Ten Percent Of Net Exposure [Member]
Derivative [Line Items]
Investment grade	0
Total	$ 0

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Derivative Financial Instruments - Summary of Credit Risk Related Contingent Features (Details) - Exelon Generation Co L L C [Member] - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Derivative [Line Items]
Derivative Asset, Fair Value, Gross Liability	$ (948)	$ (834)
Offsetting Fair Value of In-the-Money Contracts Under Master Netting Agreements	518	537
Derivative liabilities, fair value	$ (430)	$ (297)

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Derivative Financial Instruments Derivative Financial Instruments - Summary of Cash Collateral and Letters of Credit (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Collateral, Right to Reclaim Cash	$ 232	$ 511
Derivative, Collateral, Right to Reclaim Securities	242	226
Derivative, Collateral, Obligation to Return Cash	101	110
Derivative, Collateral, Obligation to Return Securities	41	40
Incremental Collateral For Loss Of Investment Grade Credit Rating	1,379	1,432
Exelon Generation Co L L C [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Derivative, Collateral, Right to Reclaim Cash	232	511
Derivative, Collateral, Right to Reclaim Securities	242	226
Derivative, Collateral, Obligation to Return Cash	101	110
Derivative, Collateral, Obligation to Return Securities	41	40
Incremental Collateral For Loss Of Investment Grade Credit Rating	$ 1,379	$ 1,432

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Debt and Credit Agreements - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($)
Short-term Debt | Exelon Generation Co L L C [Member]
Debt Instrument [Line Items]
Short-term Bank Loans and Notes Payable	$ 200
ShortTermDebt300 | Exelon Generation Co L L C [Member]
Debt Instrument [Line Items]
Short-term Bank Loans and Notes Payable	300
ShortTermDebt01252021.1 | Commonwealth Edison Co [Member]
Debt Instrument [Line Items]
Short-term Bank Loans and Notes Payable	125
ShortTermDebt01252021.2 | Commonwealth Edison Co [Member]
Debt Instrument [Line Items]
Short-term Bank Loans and Notes Payable	125
ShortTermDebt03242021 | Corporate [Member]
Debt Instrument [Line Items]
Short-term Bank Loans and Notes Payable	200
ShortTermDebt03312021.1 | Corporate [Member]
Debt Instrument [Line Items]
Short-term Bank Loans and Notes Payable	150
ShortTermDebt03312021.2 | Corporate [Member]
Debt Instrument [Line Items]
Short-term Bank Loans and Notes Payable	150
ExGenBilatJan2013 | Exelon Generation Co L L C [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum borrowing capacity	100
ExGenBilatFeb2019 | Exelon Generation Co L L C [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum borrowing capacity	100
ExGenBilatJan2016 | Exelon Generation Co L L C [Member]
Debt Instrument [Line Items]
Line of Credit Facility, Maximum borrowing capacity	150
ShortTermDebt03232017 | Corporate [Member]
Debt Instrument [Line Items]
Short-term Bank Loans and Notes Payable	$ 500
London Interbank Offered Rate (LIBOR) [Member] | Short-term Debt | Exelon Generation Co L L C [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate Terms	LIBOR plus 0.875%
London Interbank Offered Rate (LIBOR) [Member] | ShortTermDebt300 | Exelon Generation Co L L C [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate Terms	LIBOR plus 0.70%
London Interbank Offered Rate (LIBOR) [Member] | ShortTermDebt01252021.1 | Commonwealth Edison Co [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate Terms	LIBOR plus 0.50
London Interbank Offered Rate (LIBOR) [Member] | ShortTermDebt01252021.2 | Commonwealth Edison Co [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate Terms	LIBOR plus 0.75
London Interbank Offered Rate (LIBOR) [Member] | ShortTermDebt03242021 | Corporate [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate Terms	LIBOR plus 0.65
London Interbank Offered Rate (LIBOR) [Member] | ShortTermDebt03312021.1 | Corporate [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate Terms	LIBOR plus 0.65
London Interbank Offered Rate (LIBOR) [Member] | ShortTermDebt03312021.2 | Corporate [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate Terms	LIBOR plus 0.65
London Interbank Offered Rate (LIBOR) [Member] | ShortTermDebt03232017 | Corporate [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate Terms	LIBOR plus 0.65%

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Debt and Credit Agreements - Commercial Paper Borrowings (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Short-term Debt [Line Items]
Commercial Paper	$ 1,628	$ 1,031
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.52%	0.25%
Corporate [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 0
Exelon Generation Co L L C [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 1,337	$ 340
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.60%	0.27%
Commonwealth Edison Co [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 135	$ 323
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.16%	0.23%
PECO Energy Co [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 0
Baltimore Gas and Electric Company [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 156	$ 0
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.15%	0.00%
Pepco Holdings LLC [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 368
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.00%	0.24%
Potomac Electric Power Company [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 35
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.00%	0.22%
Delmarva Power and Light Company [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 146
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.00%	0.24%
Atlantic City Electric Company [Member]
Short-term Debt [Line Items]
Commercial Paper	$ 0	$ 187
Short-term Debt, Weighted Average Interest Rate, at Point in Time	0.00%	0.25%

XML

Debt and Credit Agreements - Issuance of Long-Term Debt (Details) $ in Millions	Mar. 31, 2021 USD ($)
Corporate [Member] | SoftAgree362Dec2025 | Notes Payable to Banks [Member]
Debt Instrument [Line Items]
Interest Rate	3.62%
Debt Instrument, Face Amount	$ 4
Exelon Generation Co L L C [Member] | EEPF253April2021 | Energy Efficiency Project Financing [Member]
Debt Instrument [Line Items]
Interest Rate	2.53%
Debt Instrument, Face Amount	$ 1
Commonwealth Edison Co [Member] | FMB313Mar2051 | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	3.13%
Debt Instrument, Face Amount	$ 700
PECO Energy Co [Member] | FMB305Mar2051 | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	3.05%
Debt Instrument, Face Amount	$ 375
Potomac Electric Power Company [Member] | FMB232Mar2031 | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	2.32%
Debt Instrument, Face Amount	$ 150
Potomac Electric Power Company [Member] | FMB329Sep2051 | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	3.29%
Debt Instrument, Face Amount	$ 125
Delmarva Power and Light Company [Member] | FMB324Mar2051 | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	3.24%
Debt Instrument, Face Amount	$ 125
Atlantic City Electric Company [Member] | FMB230Mar2031 | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Interest Rate	2.30%
Debt Instrument, Face Amount	$ 350

XML

Fair Value of Financial Assets and Liabilities - Narrative (Details) $ in Millions	Mar. 31, 2021 USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity Securities without Readily Determinable Fair Value, Amount	$ 61
Exelon Generation Co L L C [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Equity Securities without Readily Determinable Fair Value, Amount	50
Middle Market Lending [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	298
Middle Market Lending [Member] | Exelon Generation Co L L C [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	298
Private Equity Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	239
Private Equity Funds [Member] | Exelon Generation Co L L C [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	239
Real Estate Funds [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	344
Real Estate Funds [Member] | Exelon Generation Co L L C [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share, Unfunded Commitments	$ 344

XML

Fair Value of Financial Assets and Liabilities - Fair Value of Financial Liabilities Recorded at Amortized Cost (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt to financing trust	$ 390	$ 390
Spent Nuclear Fuel Obligation, Noncurrent	1,208	1,208
Reported Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	38,529	36,912
Long-term debt to financing trust	390	390
Spent Nuclear Fuel Obligation, Noncurrent	1,208	1,208
Estimate of Fair Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	42,370	43,752
Long-term debt to financing trust	465	467
Spent Nuclear Fuel Obligation, Noncurrent	979	909
Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Long-term debt to financing trust	0	0
Spent Nuclear Fuel Obligation, Noncurrent	0	0
Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	39,255	40,688
Long-term debt to financing trust	0	0
Spent Nuclear Fuel Obligation, Noncurrent	979	909
Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	3,115	3,064
Long-term debt to financing trust	465	467
Spent Nuclear Fuel Obligation, Noncurrent	0	0
Exelon Generation Co L L C [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Spent Nuclear Fuel Obligation, Noncurrent	1,208	1,208
Exelon Generation Co L L C [Member] | Reported Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	6,060	6,087
Spent Nuclear Fuel Obligation, Noncurrent	1,208	1,208
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	6,655	6,856
Spent Nuclear Fuel Obligation, Noncurrent	979	909
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Spent Nuclear Fuel Obligation, Noncurrent	0	0
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	5,497	5,648
Spent Nuclear Fuel Obligation, Noncurrent	979	909
Exelon Generation Co L L C [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	1,158	1,208
Spent Nuclear Fuel Obligation, Noncurrent	0	0
Commonwealth Edison Co [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt to financing trust	205	205
Commonwealth Edison Co [Member] | Reported Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	9,674	8,983
Long-term debt to financing trust	205	205
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	10,853	11,117
Long-term debt to financing trust	243	246
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Long-term debt to financing trust	0	0
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	10,853	11,117
Long-term debt to financing trust	0	0
Commonwealth Edison Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Long-term debt to financing trust	243	246
PECO Energy Co [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt to financing trust	184	184
PECO Energy Co [Member] | Reported Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	4,125	3,753
Long-term debt to financing trust	184	184
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	4,541	4,603
Long-term debt to financing trust	222	221
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Long-term debt to financing trust	0	0
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	4,491	4,553
Long-term debt to financing trust	0	0
PECO Energy Co [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	50	50
Long-term debt to financing trust	222	221
Baltimore Gas and Electric Company [Member] | Reported Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	3,665	3,664
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	3,991	4,366
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	3,991	4,366
Baltimore Gas and Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Pepco Holdings LLC [Member] | Reported Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	7,577	7,006
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	7,957	7,905
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	6,050	6,099
Pepco Holdings LLC [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	1,907	1,806
Potomac Electric Power Company [Member] | Reported Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	3,317	3,165
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	3,935	4,084
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	3,112	3,336
Potomac Electric Power Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	823	748
Delmarva Power and Light Company [Member] | Reported Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	1,802	1,677
Delmarva Power and Light Company [Member] | Estimate of Fair Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	1,910	1,939
Delmarva Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Delmarva Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	1,386	1,484
Delmarva Power and Light Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	524	455
Atlantic City Electric Company [Member] | Reported Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	1,718	1,413
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	1,862	1,620
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 1 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	0	0
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 2 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	1,302	1,018
Atlantic City Electric Company [Member] | Estimate of Fair Value Measurement [Member] | Fair Value, Inputs, Level 3 [Member]
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt (including amounts due within one year)	$ 560	$ 602

XML

Fair Value of Financial Assets and Liabilities - Fair Value Measurements of Assets and Liabilities, Recurring and Nonrecurring (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2021	Dec. 31, 2020
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Mark-to-market derivative liabilities (current liabilities)	$ 422	$ 295
Derivative Liability, Noncurrent	453	473
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	1	2
Derivative Asset, Notional Amount	2,049	1,043
Margin Deposit Assets	(148)	(209)
Derivative, Notional Amount	158	104
Unrealized Gain (Loss) on Investments	95	186
Cash and Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	1,273	409
Restricted cash member [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	93	59
Other Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	52	53
Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Net assets (liabilities) excluded from nuclear decommissioning trust fund investments	104	181
Financial Instruments Sold, Not yet Purchased, Corporate Debt	(58)	(62)
Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	968	686
DPP consideration	401	639
Assets, Fair Value Disclosure	17,923	17,776
Deferred Compensation Liability, Current and Noncurrent	(146)	(145)
Total Liabilities	(1,018)	(910)
Fair Value, Net Asset (Liability)	16,905	16,866
Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(872)	(765)
Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(3,946)	(4,265)
Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(14)	(25)
Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	3,088	3,525
Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	15,031	14,780
Fair Value, Recurring [Member] | Cash Equivalents NDT [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	604	305
Fair Value, Recurring [Member] | Equity Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	177	195
Fair Value, Recurring [Member] | Fixed Income Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	4,828	4,926
Fair Value, Recurring [Member] | Corporate Debt Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,306	1,770
Fair Value, Recurring [Member] | US Treasury and Government [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	2,071	1,997
Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	51	56
Fair Value, Recurring [Member] | State and municipal debt [Domain]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	40	101
Fair Value, Recurring [Member] | Other Fixed Income [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,360	1,002
Fair Value, Recurring [Member] | Middle Market Lending [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	813	841
Fair Value, Recurring [Member] | Private Equity Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	532	504
Fair Value, Recurring [Member] | Real Estate Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	686	679
Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	289	283
Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	60	60
Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	95	91
Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	10	11
Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	124	121
Fair Value, Recurring [Member] | Commodity Derivative Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	1,057	1,193
Fair Value, Recurring [Member] | Economic Hedging Instrument [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	3,966	4,258
Fair Value, Recurring [Member] | Proprietary Trading [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	33	44
Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	(2,942)	(3,109)
Fair Value, Recurring [Member] | Equity Securities Nuclear Decommissioning Trust Fund
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	7,568	7,525
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Collateral received from counterparties, net of collateral paid to counterparties	(104)	(67)
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	968	686
DPP consideration	0	0
Assets, Fair Value Disclosure	8,440	7,137
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	(107)	(142)
Fair Value, Net Asset (Liability)	8,333	6,995
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(107)	(142)
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(359)	(682)
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	0	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	252	540
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	7,018	5,967
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	509	210
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	177	195
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	2,070	1,871
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	2,030	1,871
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	40	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	155	151
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	60	60
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	95	91
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	122	138
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	478	745
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	0	0
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	(356)	(607)
Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Equity Securities Nuclear Decommissioning Trust Fund
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	4,439	3,886
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Collateral received from counterparties, net of collateral paid to counterparties	145	321
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
DPP consideration	401	639
Assets, Fair Value Disclosure	3,736	5,052
Deferred Compensation Liability, Current and Noncurrent	(146)	(145)
Total Liabilities	(265)	(176)
Fair Value, Net Asset (Liability)	3,471	4,876
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(119)	(31)
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(1,642)	(1,928)
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(9)	(21)
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	1,532	1,918
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	2,859	3,981
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	95	95
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,190	1,809
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,023	1,485
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	41	126
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	51	56
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	40	101
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	35	41
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	99	98
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	10	11
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	89	87
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	377	334
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	1,748	1,914
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	16	17
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	(1,387)	(1,597)
Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Equity Securities Nuclear Decommissioning Trust Fund
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,574	2,077
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Collateral received from counterparties, net of collateral paid to counterparties	105	162
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
DPP consideration	0	0
Assets, Fair Value Disclosure	1,072	1,252
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	(646)	(592)
Fair Value, Net Asset (Liability)	426	660
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(646)	(592)
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(1,945)	(1,655)
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(5)	(4)
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	1,304	1,067
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	479	497
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	283	285
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	283	285
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	196	212
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	35	34
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	35	34
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	558	721
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	1,740	1,599
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	17	27
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	(1,199)	(905)
Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Equity Securities Nuclear Decommissioning Trust Fund
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
DPP consideration	0	0
Assets, Fair Value Disclosure	4,675	4,335
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	4,675	4,335
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	4,675	4,335
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Equity Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,285	961
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,285	961
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	617	629
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	532	504
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	686	679
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	0	0
Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Equity Securities Nuclear Decommissioning Trust Fund
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,555	1,562
Exelon Generation Co L L C [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	430	297
Mark-to-market derivative liabilities (current liabilities)	392	262
Derivative Liability, Noncurrent	190	205
Derivative Instruments Not Designated as Hedging Instruments, Asset, at Fair Value	1	2
Derivative Asset, Notional Amount	2,049	1,043
Margin Deposit Assets	(148)	(209)
Derivative, Notional Amount	158	104
Unrealized Gain (Loss) on Investments	95	186
Exelon Generation Co L L C [Member] | Cash and Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	608	171
Exelon Generation Co L L C [Member] | Restricted cash member [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	29	20
Exelon Generation Co L L C [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Net assets (liabilities) excluded from nuclear decommissioning trust fund investments	104	181
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	125	124
DPP consideration	401	639
Assets, Fair Value Disclosure	16,855	16,992
Deferred Compensation Liability, Current and Noncurrent	(43)	(42)
Total Liabilities	(620)	(506)
Fair Value, Net Asset (Liability)	16,235	16,486
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(577)	(464)
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(3,651)	(3,964)
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(14)	(25)
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	3,088	3,525
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	15,031	14,780
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	604	305
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Equity Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	177	195
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	4,828	4,926
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,306	1,770
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	2,071	1,997
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	51	56
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	40	101
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,360	1,002
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	813	841
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	532	504
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	686	679
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	64	61
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	4	4
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	31	29
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	29	28
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	1,057	1,193
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	3,966	4,258
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	33	44
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	(2,942)	(3,109)
Exelon Generation Co L L C [Member] | Fair Value, Recurring [Member] | Equity Securities Nuclear Decommissioning Trust Fund
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	7,568	7,525
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Collateral received from counterparties, net of collateral paid to counterparties	(104)	(67)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	125	124
DPP consideration	0	0
Assets, Fair Value Disclosure	7,477	6,457
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	(107)	(142)
Fair Value, Net Asset (Liability)	7,370	6,315
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(107)	(142)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(359)	(682)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	252	540
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	7,018	5,967
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	509	210
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	177	195
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	2,070	1,871
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	2,030	1,871
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	40	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	35	33
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	4	4
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	31	29
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	122	138
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	478	745
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	(356)	(607)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Equity Securities Nuclear Decommissioning Trust Fund
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	4,439	3,886
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Collateral received from counterparties, net of collateral paid to counterparties	145	321
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
DPP consideration	401	639
Assets, Fair Value Disclosure	3,666	4,982
Deferred Compensation Liability, Current and Noncurrent	(43)	(42)
Total Liabilities	(162)	(73)
Fair Value, Net Asset (Liability)	3,504	4,909
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(119)	(31)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(1,642)	(1,928)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(9)	(21)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	1,532	1,918
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	2,859	3,981
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	95	95
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,190	1,809
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,023	1,485
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	41	126
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	51	56
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	40	101
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	35	41
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	29	28
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	29	28
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	377	334
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	1,748	1,914
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	16	17
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	(1,387)	(1,597)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Equity Securities Nuclear Decommissioning Trust Fund
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,574	2,077
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Collateral received from counterparties, net of collateral paid to counterparties	105	162
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
DPP consideration	0	0
Assets, Fair Value Disclosure	1,037	1,218
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	(351)	(291)
Fair Value, Net Asset (Liability)	686	927
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(351)	(291)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(1,650)	(1,354)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	(5)	(4)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	1,304	1,067
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	479	497
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Equity Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	283	285
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	283	285
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	196	212
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	558	721
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	1,740	1,599
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	17	27
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	(1,199)	(905)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Equity Securities Nuclear Decommissioning Trust Fund
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
DPP consideration	0	0
Assets, Fair Value Disclosure	4,675	4,335
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	4,675	4,335
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Commodity Derivative Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Proprietary Trading Liabilities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Effects of Netting and Allocation of Collateral Liabilites [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Total mark-to-market derivative liabilities	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	4,675	4,335
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Cash Equivalents NDT [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Equity Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Fixed Income Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,285	961
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Corporate Debt Securities [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | US Treasury and Government [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Debt Security, Government, Non-US [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | State and municipal debt [Domain]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Other Fixed Income [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,285	961
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Middle Market Lending [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	617	629
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Private Equity Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	532	504
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Real Estate Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	686	679
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Commodity Derivative Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Economic Hedging Instrument [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Proprietary Trading [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Effects of netting and allocation of collateral [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative Asset	0	0
Exelon Generation Co L L C [Member] | Fair Value Measured at Net Asset Value Per Share [Member] | Fair Value, Recurring [Member] | Equity Securities Nuclear Decommissioning Trust Fund
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	1,555	1,562
Commonwealth Edison Co [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Mark-to-market derivative liabilities (current liabilities)	31	33
Derivative Liability, Noncurrent	264	268
Commonwealth Edison Co [Member] | Cash and Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	59	83
Commonwealth Edison Co [Member] | Restricted cash member [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	40	37
Commonwealth Edison Co [Member] | Other Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	43	43
Commonwealth Edison Co [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	300	285
Assets, Fair Value Disclosure	300	285
Total mark-to-market derivative liabilities	(295)	(301)
Deferred Compensation Liability, Current and Noncurrent	(8)	(8)
Total Liabilities	(303)	(309)
Fair Value, Net Asset (Liability)	(3)	(24)
Commonwealth Edison Co [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	300	285
Assets, Fair Value Disclosure	300	285
Total mark-to-market derivative liabilities	0	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	300	285
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	0	0
Total mark-to-market derivative liabilities	0	0
Deferred Compensation Liability, Current and Noncurrent	(8)	(8)
Total Liabilities	(8)	(8)
Fair Value, Net Asset (Liability)	(8)	(8)
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	0	0
Total mark-to-market derivative liabilities	(295)	(301)
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	(295)	(301)
Fair Value, Net Asset (Liability)	(295)	(301)
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
PECO Energy Co [Member] | Cash and Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	48	18
PECO Energy Co [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	7	8
Assets, Fair Value Disclosure	29	30
Total mark-to-market derivative liabilities	0	0
Deferred Compensation Liability, Current and Noncurrent	(9)	(9)
Total Liabilities	(9)	(9)
Fair Value, Net Asset (Liability)	20	21
PECO Energy Co [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	22	22
PECO Energy Co [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	9	9
PECO Energy Co [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	13	13
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	7	8
Assets, Fair Value Disclosure	16	17
Total mark-to-market derivative liabilities	0	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	16	17
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	9	9
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	9	9
PECO Energy Co [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	13	13
Total mark-to-market derivative liabilities	0	0
Deferred Compensation Liability, Current and Noncurrent	(9)	(9)
Total Liabilities	(9)	(9)
Fair Value, Net Asset (Liability)	4	4
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	13	13
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
PECO Energy Co [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	13	13
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	0	0
Total mark-to-market derivative liabilities	0	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	0	0
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
PECO Energy Co [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Baltimore Gas and Electric Company [Member] | Cash and Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	21	24
Baltimore Gas and Electric Company [Member] | Restricted cash member [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	1	1
Baltimore Gas and Electric Company [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	120
Assets, Fair Value Disclosure	11	130
Total mark-to-market derivative liabilities	0	0
Deferred Compensation Liability, Current and Noncurrent	(6)	(5)
Total Liabilities	(6)	(5)
Fair Value, Net Asset (Liability)	5	125
Baltimore Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	11	10
Baltimore Gas and Electric Company [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	11	10
Baltimore Gas and Electric Company [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	120
Assets, Fair Value Disclosure	11	130
Total mark-to-market derivative liabilities	0	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	11	130
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	11	10
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	11	10
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	0	0
Total mark-to-market derivative liabilities	0	0
Deferred Compensation Liability, Current and Noncurrent	(6)	(5)
Total Liabilities	(6)	(5)
Fair Value, Net Asset (Liability)	(6)	(5)
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	0	0
Total mark-to-market derivative liabilities	0	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	0	0
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Baltimore Gas and Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Pepco Holdings LLC [Member] | Cash and Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	72	74
Pepco Holdings LLC [Member] | Restricted cash member [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	5	0
Pepco Holdings LLC [Member] | Other Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	9	10
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	527	86
Assets, Fair Value Disclosure	666	226
Deferred Compensation Liability, Current and Noncurrent	(16)	(17)
Total Liabilities	(16)	(17)
Fair Value, Net Asset (Liability)	650	209
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	139	140
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	53	55
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	15	14
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	10	11
Pepco Holdings LLC [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	61	60
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	527	86
Assets, Fair Value Disclosure	595	155
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	595	155
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	68	69
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	53	55
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	15	14
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	36	37
Deferred Compensation Liability, Current and Noncurrent	(16)	(17)
Total Liabilities	(16)	(17)
Fair Value, Net Asset (Liability)	20	20
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	36	37
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	10	11
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	26	26
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	35	34
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	35	34
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	35	34
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Mutual Funds [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	35	34
Potomac Electric Power Company [Member] | Cash and Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	34	30
Potomac Electric Power Company [Member] | Restricted cash member [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	5	0
Potomac Electric Power Company [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	128	35
Assets, Fair Value Disclosure	244	150
Deferred Compensation Liability, Current and Noncurrent	(2)	(2)
Total Liabilities	(2)	(2)
Fair Value, Net Asset (Liability)	242	148
Potomac Electric Power Company [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	116	115
Potomac Electric Power Company [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	53	53
Potomac Electric Power Company [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	2	2
Potomac Electric Power Company [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	61	60
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	128	35
Assets, Fair Value Disclosure	181	88
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	181	88
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	53	53
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	53	53
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	28	28
Deferred Compensation Liability, Current and Noncurrent	(2)	(2)
Total Liabilities	(2)	(2)
Fair Value, Net Asset (Liability)	26	26
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	28	28
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	2	2
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	26	26
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	35	34
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	35	34
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	35	34
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	35	34
Delmarva Power and Light Company [Member] | Cash and Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	14	15
Delmarva Power and Light Company [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	50	0
Assets, Fair Value Disclosure	50	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	50	0
Delmarva Power and Light Company [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	50	0
Assets, Fair Value Disclosure	50	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	50	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	0	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	0	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Delmarva Power and Light Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Cash and Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	17	17
Atlantic City Electric Company [Member] | Other Assets [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	9	10
Atlantic City Electric Company [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	349	13
Assets, Fair Value Disclosure	349	13
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	349	13
Atlantic City Electric Company [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	349	13
Assets, Fair Value Disclosure	349	13
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	349	13
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 1 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	0	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 2 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Cash equivalents	0	0
Assets, Fair Value Disclosure	0	0
Deferred Compensation Liability, Current and Noncurrent	0	0
Total Liabilities	0	0
Fair Value, Net Asset (Liability)	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Rabbi Trust Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Cash Equivalents [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | Fixed Income Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Atlantic City Electric Company [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Recurring [Member] | 6311 Life Insurance [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Investments, Fair Value Disclosure	0	0
Exelon Generation Co LLC Affiliate [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Financial Instruments Sold, Not yet Purchased, Corporate Debt	(58)	(62)
Maturity Less than 30 Days [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative, Collateral, Right to Reclaim Cash	108	116
Maturity Less than 30 Days [Member] | Exelon Generation Co L L C [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value, Assets, Liabilities and Stockholders' Equity Measured on Recurring Basis [Abstract]
Derivative, Collateral, Right to Reclaim Cash	$ 108	$ 116

XML

Fair Value of Financial Assets and Liabilities - Fair Value Assets Liabilities Measured On Recurring Basis Unobservable Input Reconciliation (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Fair Value, Inputs, Level 3 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	$ 660	$ 1,068
Total realized / unrealized gains (losses)
Included in net income	(276)	10
Included in noncurrent payables to affiliates	0	0
Included in regulatory assets	7	(14)
Change in collateral	(57)	1
Purchases, sales, issuances and settlements
Purchases	109	42
Sales	1	(22)
Settlements	(20)	(14)
Transfers into Level 3		2
Transfers out of Level 3	2	15
Ending Balance	426	1,088
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	(147)	187
Fair Value, Inputs, Level 3 [Member] | Consolidation, Eliminations [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	0	0
Total realized / unrealized gains (losses)
Included in net income	0	0
Included in noncurrent payables to affiliates	(1)	1
Included in regulatory assets	1	(1)
Change in collateral	0	0
Purchases, sales, issuances and settlements
Purchases	0	0
Sales	0	0
Settlements	0	0
Transfers into Level 3		0
Transfers out of Level 3	0	0
Ending Balance	0	0
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	0	0
Exelon Generation Co L L C [Member]
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Abstract]
Fair Value, Assets and Liabilities Measured on Recurring Basis, Gain (Loss) Included in Earnings	129	177
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	927	1,328
Total realized / unrealized gains (losses)
Included in net income	(277)	9
Included in noncurrent payables to affiliates	1	(1)
Included in regulatory assets	0	0
Change in collateral	(57)	1
Purchases, sales, issuances and settlements
Purchases	109	42
Sales	1	(22)
Settlements	(20)	(14)
Transfers into Level 3		2
Transfers out of Level 3	2	15
Ending Balance	686	1,360
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	(148)	186
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Nuclear Decommissioning Trust Fund Investments [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	497	511
Total realized / unrealized gains (losses)
Included in net income	1	(1)
Included in noncurrent payables to affiliates	1	(1)
Included in regulatory assets	0	0
Change in collateral	0	0
Purchases, sales, issuances and settlements
Purchases	0	3
Sales	0	0
Settlements	(20)	(14)
Transfers into Level 3		0
Transfers out of Level 3	0	0
Ending Balance	479	498
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	1	(1)
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	430	817
Total realized / unrealized gains (losses)
Included in net income	(278)	10
Included in noncurrent payables to affiliates	0	0
Included in regulatory assets	0	0
Change in collateral	(57)	1
Purchases, sales, issuances and settlements
Purchases	109	39
Sales	1	(22)
Settlements	0	0
Transfers into Level 3		2
Transfers out of Level 3	2	15
Ending Balance	207	862
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	(149)	187
Commonwealth Edison Co [Member] | Derivative [Member] | Interest Rate Swap [Member]
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Abstract]
Realized Investment Gains (Losses)	8	10
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	(301)	(301)
Total realized / unrealized gains (losses)
Included in net income	0	0
Included in noncurrent payables to affiliates	0	0
Included in regulatory assets	6	(13)
Change in collateral	0	0
Purchases, sales, issuances and settlements
Purchases	0	0
Sales	0	0
Settlements	0	0
Transfers into Level 3		0
Transfers out of Level 3	0	0
Ending Balance	(295)	(314)
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	0	0
Footnotes To Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Abstract]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Period Increase (Decrease)	(2)	(23)
Pepco Holdings LLC [Member] | Fair Value, Inputs, Level 3 [Member] | 6311 Life Insurance [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	34	41
Total realized / unrealized gains (losses)
Included in net income	1	1
Included in noncurrent payables to affiliates	0	0
Included in regulatory assets	0	0
Change in collateral	0	0
Purchases, sales, issuances and settlements
Purchases	0	0
Sales	0	0
Settlements	0	0
Transfers into Level 3		0
Transfers out of Level 3	0	0
Ending Balance	35	42
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	1	1
Potomac Electric Power Company [Member] | Fair Value, Inputs, Level 3 [Member] | 6311 Life Insurance [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance	34	41
Total realized / unrealized gains (losses)
Included in net income	1	1
Included in noncurrent payables to affiliates	0	0
Included in regulatory assets	0	0
Change in collateral	0	0
Purchases, sales, issuances and settlements
Purchases	0	0
Sales	0	0
Settlements	0	0
Transfers into Level 3		0
Transfers out of Level 3	0	0
Ending Balance	35	42
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	$ 1	$ 1

XML

Fair Value of Financial Assets and Liabilities - Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings (Details) - Fair Value, Inputs, Level 3 [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	$ 276	$ (10)
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	(147)	187
Operating Revenue [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	(116)	72
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	(65)	205
Purchased Power And Fuel [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	(162)	(62)
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	(84)	(18)
Operating and Maintenance [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	1	1
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	1	1
Other, net [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	1	(1)
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	1	(1)
Exelon Generation Co L L C [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	277	(9)
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	(148)	186
Exelon Generation Co L L C [Member] | Operating Revenue [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	(116)	72
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	(65)	205
Exelon Generation Co L L C [Member] | Purchased Power And Fuel [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	(162)	(62)
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	(84)	(18)
Exelon Generation Co L L C [Member] | Other, net [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	1	(1)
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	1	(1)
Pepco Holdings LLC [Member] | Operating and Maintenance [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	1	1
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	1	1
Potomac Electric Power Company [Member] | Operating and Maintenance [Member]
Fair Value Assets And Liabilities Measured On Recurring Basis Gain Loss Included In Earnings [Line Items]
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Gain (Loss) Included in Earnings	1	1
Fair Value, Asset, Recurring Basis, Still Held, Unrealized Gain (Loss)	$ 1	$ 1

XML

Fair Value of Financial Assets and Liabilities - Fair Value Inputs Assets Quantitative Information (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Fair Value, Inputs, Level 3 [Member]
Derivatives Fair Value Footnotes [Abstract]
Cash Collateral Posted	$ 105,000,000	$ 162,000,000
Fair Value, Inputs, Level 3 [Member] | Economic Hedges [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	90,000,000	245,000,000
Fair Value, Inputs, Level 3 [Member] | Derivative [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	$ (295,000,000)	$ (301,000,000)
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	1.35	2.25
Forward gas price assets	1.42	1.57
Derivative Asset (Liability) Net, Measurement Input	0.03	0.03
Forward heat rate	800.00%	800.00%
Fair Value Inputs Renewable Factor	90.00%	91.00%
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	235	163
Forward gas price assets	8.18	7.88
Derivative Asset (Liability) Net, Measurement Input	0.08	0.08
Forward heat rate	900.00%	900.00%
Fair Value Inputs Renewable Factor	123.00%	123.00%
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Arithmetic Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	32	30
Forward gas price assets	2.59	2.59
Derivative Asset (Liability) Net, Measurement Input	0.0493	0.0493
Forward heat rate	885.00%	885.00%
Fair Value Inputs Renewable Factor	99.00%	99.00%
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.11	0.11
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	1.16	2.37
Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Arithmetic Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.27	0.32
Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	$ 12,000,000	$ 23,000,000
Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	9	10
Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	102	106
Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Arithmetic Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	30	27
Exelon Generation Co L L C [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	$ 430,000,000	$ 297,000,000
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member]
Derivatives Fair Value Footnotes [Abstract]
Cash Collateral Posted	105,000,000	162,000,000
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Economic Hedges [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	$ 90,000,000	$ 245,000,000
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	1.35	2.25
Forward gas price assets	1.42	1.57
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	235	163
Forward gas price assets	8.18	7.88
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Arithmetic Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	32	30
Forward gas price assets	2.59	2.59
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.11	0.11
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	1.16	2.37
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Option Model Valuation Technique [Member] | Arithmetic Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.27	0.32
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	$ 12,000,000	$ 23,000,000
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	9	10
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	102	106
Exelon Generation Co L L C [Member] | Fair Value, Inputs, Level 3 [Member] | Proprietary Trading [Member] | Discounted Cash Flow [Member] | Arithmetic Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Forward power price assets	30	27
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member]
Derivatives, Fair Value [Line Items]
Derivative Liability, Fair Value, Amount Not Offset Against Collateral	$ (295,000,000)	$ (301,000,000)
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Minimum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.03	0.03
Forward heat rate	800.00%	800.00%
Fair Value Inputs Renewable Factor	90.00%	91.00%
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Maximum [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.08	0.08
Forward heat rate	900.00%	900.00%
Fair Value Inputs Renewable Factor	123.00%	123.00%
Commonwealth Edison Co [Member] | Fair Value, Inputs, Level 3 [Member] | Derivative [Member] | Discounted Cash Flow [Member] | Arithmetic Average [Member]
Fair Value Measurement Inputs and Valuation Techniques [Abstract]
Derivative Asset (Liability) Net, Measurement Input	0.0493	0.0493
Forward heat rate	885.00%	885.00%
Fair Value Inputs Renewable Factor	99.00%	99.00%

XML

Commitments and Contingencies - Narrative (Details) $ in Millions		3 Months Ended		9 Months Ended	12 Months Ended
	Mar. 23, 2016 USD ($) MW	Mar. 31, 2021 USD ($) MGPSite Open_claim MW	Mar. 31, 2020 MW	Sep. 30, 2018 MW	Dec. 31, 2022 MW	Dec. 31, 2020 USD ($)
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		$ 3,123
Accrual for Environmental Loss Contingencies, Gross		473				$ 483
Liability for Asbestos and Environmental Claims, Gross		88				89
Exelon Generation Co L L C [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		2,555
Accrual for Environmental Loss Contingencies, Gross		119				121
Liability for Asbestos and Environmental Claims, Gross		88				89
Exelon Generation Co L L C [Member] | LDC Damages
Commitments And Contingencies Additional Narrative Information [Line Items]
LDC Damages		40
Exelon Generation Co L L C [Member] | LDC Damages - Accrued Liability
Commitments And Contingencies Additional Narrative Information [Line Items]
LDC Damages		40
Commonwealth Edison Co [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		$ 224
Mgp Site Contingency Monitoring Count | MGPSite		21
Accrual for Environmental Loss Contingencies, Gross		$ 281				293
Deferred Prosecution Agreement Payments						200
PECO Energy Co [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		$ 180
Mgp Site Contingency Monitoring Count | MGPSite		8
Accrual for Environmental Loss Contingencies, Gross		$ 23				23
Baltimore Gas and Electric Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		$ 6
Mgp Site Contingency Monitoring Count | MGPSite		4
Accrual for Environmental Loss Contingencies, Gross		$ 6				2
Pepco Holdings LLC [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		52
Accrual for Environmental Loss Contingencies, Gross		44				44
Potomac Electric Power Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		24
Accrual for Environmental Loss Contingencies, Gross		42				42
Delmarva Power and Light Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		$ 17
Mgp Site Contingency Count | MGPSite		1
Accrual for Environmental Loss Contingencies, Gross		$ 1				$ 1
Open Claims [Member] | Exelon Generation Co L L C [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Liability for Asbestos and Environmental Claims, Gross		$ 24
Open Asbestos Related Personal Injury Claims | Open_claim		243
Estimated Future Claims [Member] | Exelon Generation Co L L C [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Liability for Asbestos and Environmental Claims, Gross		$ 64
Pepco Holdings Inc [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		513
Pepco Holdings Inc [Member] | Pepco Holdings LLC [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		320
Pepco Holdings Inc [Member] | Potomac Electric Power Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		120
Pepco Holdings Inc [Member] | Delmarva Power and Light Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		89
West Lake [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Accrual for Environmental Loss Contingencies, Gross		280
West Lake [Member] | Exelon Generation Co L L C [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Accrual for Environmental Loss Contingencies, Gross		30
Accrual for Environmental Loss Contingencies, Component Amount		90
Other Solar Projects [Member] | Pepco Holdings Inc [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Business Acquisition, Expected New Generation Mwh | MW	37
Other Commitment	$ 135	$ 121
Other Non-Financial Commitment | MW		27
Other Solar Projects [Member] | Pepco Holdings Inc [Member] | Exelon Generation Co L L C [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Commitment		$ 121
Wind Assets [Member] | Pepco Holdings Inc [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Other Non-Financial Commitment | MW	100
Wind Assets [Member] | Pepco Holdings Inc [Member] | Delmarva Power and Light Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Purchase Commitment | MW	120		40	40
Subsequent Event [Member] | Wind Assets [Member] | Pepco Holdings Inc [Member] | Delmarva Power and Light Company [Member]
Commitments And Contingencies Additional Narrative Information [Line Items]
Purchase Commitment | MW					40

XML

Commitments and Contingencies - Merger Commitment (Details) $ in Millions	Mar. 31, 2021 USD ($)
Other Commitments [Line Items]
Other Commitment	$ 3,123
Pepco Holdings LLC [Member]
Other Commitments [Line Items]
Other Commitment	52
Potomac Electric Power Company [Member]
Other Commitments [Line Items]
Other Commitment	24
Delmarva Power and Light Company [Member]
Other Commitments [Line Items]
Other Commitment	17
Atlantic City Electric Company [Member]
Other Commitments [Line Items]
Other Commitment	11
Pepco Holdings Inc [Member]
Other Commitments [Line Items]
Other Commitment	513
Pepco Holdings Inc [Member] | Remaining commitment
Other Commitments [Line Items]
Other Commitment	79
Pepco Holdings Inc [Member] | Pepco Holdings LLC [Member]
Other Commitments [Line Items]
Other Commitment	320
Pepco Holdings Inc [Member] | Pepco Holdings LLC [Member] | Remaining commitment
Other Commitments [Line Items]
Other Commitment	64
Pepco Holdings Inc [Member] | Potomac Electric Power Company [Member]
Other Commitments [Line Items]
Other Commitment	120
Pepco Holdings Inc [Member] | Potomac Electric Power Company [Member] | Remaining commitment
Other Commitments [Line Items]
Other Commitment	53
Pepco Holdings Inc [Member] | Delmarva Power and Light Company [Member]
Other Commitments [Line Items]
Other Commitment	89
Pepco Holdings Inc [Member] | Delmarva Power and Light Company [Member] | Remaining commitment
Other Commitments [Line Items]
Other Commitment	7
Pepco Holdings Inc [Member] | Atlantic City Electric Company [Member]
Other Commitments [Line Items]
Other Commitment	111
Pepco Holdings Inc [Member] | Atlantic City Electric Company [Member] | Remaining commitment
Other Commitments [Line Items]
Other Commitment	$ 4

XML

Commitments and Contingencies - Schedule of Commercial Commitments (Details) $ in Millions	Mar. 31, 2021 USD ($)
Other Commitments [Line Items]
Other Commitment	$ 3,123
Other Commitment, to be Paid, Remainder of Fiscal Year	2,075
Other Commitment, to be Paid, Year Two	644
Other Commitment, to be Paid, Year Three	4
Other Commitment, to be Paid, Year Four	6
Other Commitment, to be Paid, Year Five	5
Other Commitment, to be Paid, after Year Five	389
Guarantor Obligations, Maximum Exposure, Undiscounted	73
Letters of Credit
Other Commitments [Line Items]
Other Commitment	1,639
Other Commitment, to be Paid, Remainder of Fiscal Year	1,156
Other Commitment, to be Paid, Year Two	483
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Surety Bonds
Other Commitments [Line Items]
Other Commitment	1,077
Other Commitment, to be Paid, Remainder of Fiscal Year	919
Other Commitment, to be Paid, Year Two	158
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Financing trust guarantees
Other Commitments [Line Items]
Other Commitment	378
Other Commitment, to be Paid, Remainder of Fiscal Year	0
Other Commitment, to be Paid, Year Two	0
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	378
Guaranteed lease residual values
Other Commitments [Line Items]
Other Commitment	29
Other Commitment, to be Paid, Remainder of Fiscal Year	0
Other Commitment, to be Paid, Year Two	3
Other Commitment, to be Paid, Year Three	4
Other Commitment, to be Paid, Year Four	6
Other Commitment, to be Paid, Year Five	5
Other Commitment, to be Paid, after Year Five	11
Exelon Generation Co L L C [Member]
Other Commitments [Line Items]
Other Commitment	2,555
Other Commitment, to be Paid, Remainder of Fiscal Year	1,935
Other Commitment, to be Paid, Year Two	620
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Exelon Generation Co L L C [Member] | Letters of Credit
Other Commitments [Line Items]
Other Commitment	1,623
Other Commitment, to be Paid, Remainder of Fiscal Year	1,141
Other Commitment, to be Paid, Year Two	482
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Exelon Generation Co L L C [Member] | Surety Bonds
Other Commitments [Line Items]
Other Commitment	932
Other Commitment, to be Paid, Remainder of Fiscal Year	794
Other Commitment, to be Paid, Year Two	138
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Commonwealth Edison Co [Member]
Other Commitments [Line Items]
Other Commitment	224
Other Commitment, to be Paid, Remainder of Fiscal Year	21
Other Commitment, to be Paid, Year Two	3
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	200
Commonwealth Edison Co [Member] | Letters of Credit
Other Commitments [Line Items]
Other Commitment	7
Other Commitment, to be Paid, Remainder of Fiscal Year	7
Other Commitment, to be Paid, Year Two	0
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Commonwealth Edison Co [Member] | Surety Bonds
Other Commitments [Line Items]
Other Commitment	17
Other Commitment, to be Paid, Remainder of Fiscal Year	14
Other Commitment, to be Paid, Year Two	3
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Commonwealth Edison Co [Member] | Financing trust guarantees
Other Commitments [Line Items]
Other Commitment	200
Other Commitment, to be Paid, Remainder of Fiscal Year	0
Other Commitment, to be Paid, Year Two	0
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	200
PECO Energy Co [Member]
Other Commitments [Line Items]
Other Commitment	180
Other Commitment, to be Paid, Remainder of Fiscal Year	2
Other Commitment, to be Paid, Year Two	0
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	178
PECO Energy Co [Member] | Surety Bonds
Other Commitments [Line Items]
Other Commitment	2
Other Commitment, to be Paid, Remainder of Fiscal Year	2
Other Commitment, to be Paid, Year Two	0
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
PECO Energy Co [Member] | Financing trust guarantees
Other Commitments [Line Items]
Other Commitment	178
Other Commitment, to be Paid, Remainder of Fiscal Year	0
Other Commitment, to be Paid, Year Two	0
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	178
Baltimore Gas and Electric Company [Member]
Other Commitments [Line Items]
Other Commitment	6
Other Commitment, to be Paid, Remainder of Fiscal Year	5
Other Commitment, to be Paid, Year Two	1
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Baltimore Gas and Electric Company [Member] | Letters of Credit
Other Commitments [Line Items]
Other Commitment	3
Other Commitment, to be Paid, Remainder of Fiscal Year	2
Other Commitment, to be Paid, Year Two	1
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Baltimore Gas and Electric Company [Member] | Surety Bonds
Other Commitments [Line Items]
Other Commitment	3
Other Commitment, to be Paid, Remainder of Fiscal Year	3
Other Commitment, to be Paid, Year Two	0
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Pepco Holdings LLC [Member]
Other Commitments [Line Items]
Other Commitment	52
Other Commitment, to be Paid, Remainder of Fiscal Year	20
Other Commitment, to be Paid, Year Two	6
Other Commitment, to be Paid, Year Three	4
Other Commitment, to be Paid, Year Four	6
Other Commitment, to be Paid, Year Five	5
Other Commitment, to be Paid, after Year Five	11
Guarantor Obligations, Maximum Exposure, Undiscounted	73
Pepco Holdings LLC [Member] | Surety Bonds
Other Commitments [Line Items]
Other Commitment	23
Other Commitment, to be Paid, Remainder of Fiscal Year	20
Other Commitment, to be Paid, Year Two	3
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Pepco Holdings LLC [Member] | Guaranteed lease residual values
Other Commitments [Line Items]
Other Commitment	29
Other Commitment, to be Paid, Remainder of Fiscal Year	0
Other Commitment, to be Paid, Year Two	3
Other Commitment, to be Paid, Year Three	4
Other Commitment, to be Paid, Year Four	6
Other Commitment, to be Paid, Year Five	5
Other Commitment, to be Paid, after Year Five	11
Potomac Electric Power Company [Member]
Other Commitments [Line Items]
Other Commitment	24
Other Commitment, to be Paid, Remainder of Fiscal Year	14
Other Commitment, to be Paid, Year Two	1
Other Commitment, to be Paid, Year Three	1
Other Commitment, to be Paid, Year Four	2
Other Commitment, to be Paid, Year Five	2
Other Commitment, to be Paid, after Year Five	4
Guarantor Obligations, Maximum Exposure, Undiscounted	25
Potomac Electric Power Company [Member] | Surety Bonds
Other Commitments [Line Items]
Other Commitment	14
Other Commitment, to be Paid, Remainder of Fiscal Year	14
Other Commitment, to be Paid, Year Two	0
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Potomac Electric Power Company [Member] | Guaranteed lease residual values
Other Commitments [Line Items]
Other Commitment	10
Other Commitment, to be Paid, Remainder of Fiscal Year	0
Other Commitment, to be Paid, Year Two	1
Other Commitment, to be Paid, Year Three	1
Other Commitment, to be Paid, Year Four	2
Other Commitment, to be Paid, Year Five	2
Other Commitment, to be Paid, after Year Five	4
Delmarva Power and Light Company [Member]
Other Commitments [Line Items]
Other Commitment	17
Other Commitment, to be Paid, Remainder of Fiscal Year	2
Other Commitment, to be Paid, Year Two	4
Other Commitment, to be Paid, Year Three	2
Other Commitment, to be Paid, Year Four	3
Other Commitment, to be Paid, Year Five	2
Other Commitment, to be Paid, after Year Five	4
Guarantor Obligations, Maximum Exposure, Undiscounted	30
Delmarva Power and Light Company [Member] | Surety Bonds
Other Commitments [Line Items]
Other Commitment	5
Other Commitment, to be Paid, Remainder of Fiscal Year	2
Other Commitment, to be Paid, Year Two	3
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Delmarva Power and Light Company [Member] | Guaranteed lease residual values
Other Commitments [Line Items]
Other Commitment	12
Other Commitment, to be Paid, Remainder of Fiscal Year	0
Other Commitment, to be Paid, Year Two	1
Other Commitment, to be Paid, Year Three	2
Other Commitment, to be Paid, Year Four	3
Other Commitment, to be Paid, Year Five	2
Other Commitment, to be Paid, after Year Five	4
Atlantic City Electric Company [Member]
Other Commitments [Line Items]
Other Commitment	11
Other Commitment, to be Paid, Remainder of Fiscal Year	4
Other Commitment, to be Paid, Year Two	1
Other Commitment, to be Paid, Year Three	1
Other Commitment, to be Paid, Year Four	1
Other Commitment, to be Paid, Year Five	1
Other Commitment, to be Paid, after Year Five	3
Guarantor Obligations, Maximum Exposure, Undiscounted	18
Atlantic City Electric Company [Member] | Surety Bonds
Other Commitments [Line Items]
Other Commitment	4
Other Commitment, to be Paid, Remainder of Fiscal Year	4
Other Commitment, to be Paid, Year Two	0
Other Commitment, to be Paid, Year Three	0
Other Commitment, to be Paid, Year Four	0
Other Commitment, to be Paid, Year Five	0
Other Commitment, to be Paid, after Year Five	0
Atlantic City Electric Company [Member] | Guaranteed lease residual values
Other Commitments [Line Items]
Other Commitment	7
Other Commitment, to be Paid, Remainder of Fiscal Year	0
Other Commitment, to be Paid, Year Two	1
Other Commitment, to be Paid, Year Three	1
Other Commitment, to be Paid, Year Four	1
Other Commitment, to be Paid, Year Five	1
Other Commitment, to be Paid, after Year Five	$ 3
Maximum [Member] | Guaranteed lease residual values
Other Commitments [Line Items]
Lessor, Operating Lease, Term of Contract	8 years
Minimum [Member] | Guaranteed lease residual values
Other Commitments [Line Items]
Lessor, Operating Lease, Term of Contract	1 year

XML

Commitments and Contingencies - Schedule of Accruals for Environmental Matters (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	$ 473	$ 483
Exelon Generation Co L L C [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	119	121
Commonwealth Edison Co [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	281	293
PECO Energy Co [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	23	23
Baltimore Gas and Electric Company [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	6	2
Pepco Holdings LLC [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	44	44
Potomac Electric Power Company [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	42	42
Delmarva Power and Light Company [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	1	1
Atlantic City Electric Company [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	1	1
Accrual For MGP Investigation And Remediation [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	306	314
Accrual For MGP Investigation And Remediation [Member] | Exelon Generation Co L L C [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	0	0
Accrual For MGP Investigation And Remediation [Member] | Commonwealth Edison Co [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	280	293
Accrual For MGP Investigation And Remediation [Member] | PECO Energy Co [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	21	21
Accrual For MGP Investigation And Remediation [Member] | Baltimore Gas and Electric Company [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	5	0
Accrual For MGP Investigation And Remediation [Member] | Pepco Holdings LLC [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	0	0
Accrual For MGP Investigation And Remediation [Member] | Potomac Electric Power Company [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	0	0
Accrual For MGP Investigation And Remediation [Member] | Delmarva Power and Light Company [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	0	0
Accrual For MGP Investigation And Remediation [Member] | Atlantic City Electric Company [Member]
Accrual For Environmental Loss Contingencies [Line Items]
Total environmental investigation and remediation reserve	$ 0	$ 0

XML

Changes in Accumulated Other Comprehensive Income - Schedule of Changes in AOCI (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	$ 34,868	$ 34,573
Other comprehensive income	54	21
Ending balance	34,313	34,616
Gains (Losses) on Cash Flow Hedges
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	(5)	(2)
OCI before reclassifications	0	(1)
Amounts reclassified from AOCI	0	0
Other comprehensive income	0	(1)
Ending balance	(5)	(3)
Pension and Non-Pension Postretirement Benefit Plan Items
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	(3,372)	(3,165)
OCI before reclassifications	(2)	(7)
Amounts reclassified from AOCI	55	37
Other comprehensive income	53	30
Ending balance	(3,319)	(3,135)
Foreign Currency Items
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	(23)	(27)
OCI before reclassifications	1	(8)
Amounts reclassified from AOCI	0	0
Other comprehensive income	1	(8)
Ending balance	(22)	(35)
Total
Movement in Accumulated Other Comprehensive Income [Roll Forward]
Beginning balance	(3,400)	(3,194)
OCI before reclassifications	(1)	(16)
Amounts reclassified from AOCI	55	37
Other comprehensive income	54	21
Ending balance	$ (3,346)	$ (3,173)

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Changes in Accumulated Other Comprehensive Income - Income Taxes Allocated to Other Comprehensive Income (Loss) Components (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Prior service costs
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Tax	$ 1	$ 4
Actuarial losses
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Tax	(19)	(17)
Pension and Non-Pension Postretirement Benefit Plan Items
Accumulated Other Comprehensive Income (Loss) [Line Items]
Other Comprehensive Income (Loss), Tax	$ 0	$ 3

XML

Variable Interest Entities - Narrative (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020	Apr. 01, 2014
Variable Interest Entity [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 73
Distributed Energy Company
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	90.00%	90.00%
VIE Distributed Energy Company
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	90.00%	90.00%
Exelon Generation Co L L C [Member] | Distributed Energy Company
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	90.00%	90.00%
Exelon Generation Co L L C [Member] | VIE Distributed Energy Company
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	90.00%	90.00%
CENG [Member]
Variable Interest Entity [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	49.99%
Equity Method Investment, Ownership Percentage	50.01%	50.01%
CENG [Member] | Payment Guarantee [Member]
Variable Interest Entity [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted			$ 245
CENG [Member] | Financial Guarantee [Member]
Variable Interest Entity [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted			$ 165
CENG [Member] | Exelon Generation Co L L C [Member]
Variable Interest Entity [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	49.99%
Guarantor Obligations, Current Carrying Value	$ 688
Equity Method Investment, Ownership Percentage	50.01%	50.01%
EGRP [Member]
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	51.00%	51.00%
EGRP [Member] | Exelon Generation Co L L C [Member]
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	51.00%	51.00%
EGRP [Member] | Exelon Generation Co L L C [Member] | Wind project entities [Member]
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	100.00%
EGRP [Member] | Exelon Generation Co L L C [Member] | Solar project entities [Member]
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	100.00%
Antelope Valley [Member]
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	100.00%	100.00%
Antelope Valley [Member] | Exelon Generation Co L L C [Member]
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	100.00%	100.00%
Distributed Energy Company
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	31.00%	31.00%
Distributed Energy Company | Exelon Generation Co L L C [Member]
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	31.00%	31.00%
NER
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	100.00%	100.00%
NER | Exelon Generation Co L L C [Member]
Variable Interest Entity [Line Items]
Equity Method Investment, Ownership Percentage	100.00%	100.00%

XML

Variable Interest Entities - Assets and Liabilities of Consolidated VIES (Details) - USD ($) $ in Millions		Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019
Variable Interest Entity [Line Items]
Cash and cash equivalents		$ 1,908	$ 663	$ 1,457	$ 587
Restricted cash and cash equivalents		374	438	414	358
Accounts receivable, net
Customer		3,575	3,231
Unamortized energy contract assets		38	38
Inventory, net
Materials and supplies		1,427	1,425
Assets held for sale		11	958
Other current assets		1,687	1,609
Total current assets		12,997	12,562
Property, plant and equipment, net		82,588	82,584
NDT funds		14,688	14,464
Unamortized energy contract assets		285	294
Other Assets, Noncurrent		3,033	2,982
Total assets	[1]	130,000	129,317
Long-term debt due within one year		2,281	1,819
Accounts payable		3,430	3,562
Accrued expenses		1,729	2,078
Unamortized energy contract liabilities		98	100
Liabilities held for sale		3	375
Other		1,176	1,264
Total current liabilities		13,580	12,771
Long-term debt		36,248	35,093
Asset retirement obligations, noncurrent		12,405	12,300
Unamortized energy contract liabilities		217	238
Other		2,988	2,942
Total liabilities	[1]	95,687	94,449
Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Cash and cash equivalents		175	98
Restricted cash and cash equivalents		37	47
Accounts receivable, net
Customer		145	148
Other		35	36
Unamortized energy contract assets		22	22
Inventory, net
Materials and supplies		242	244
Assets held for sale		0	101
Other current assets		448	674
Total current assets		1,104	1,370
Property, plant and equipment, net		5,747	5,803
NDT funds		3,089	3,007
Unamortized energy contract assets		243	249
Other Assets, Noncurrent		47	52
Total noncurrent assets		9,126	9,111
Total assets		10,230	10,481
Long-term debt due within one year		90	94
Accounts payable		95	81
Accrued expenses		67	70
Unamortized energy contract liabilities		3	4
Liabilities held for sale		0	16
Other		1	5
Total current liabilities		256	270
Long-term debt		861	889
Asset retirement obligations, noncurrent		2,347	2,318
Other		116	129
Total noncurrent liabilities		3,324	3,336
Total liabilities		3,580	3,606
PP&E - unrestricted asset		1	1
Other Assets		0	9
Exelon Generation Co L L C [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Inventory, net
Unamortized energy contract assets		222
Recourse [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Inventory, net
Total liabilities		2	8
Exelon Generation Co L L C [Member]
Variable Interest Entity [Line Items]
Cash and cash equivalents		721	226	821	303
Restricted cash and cash equivalents		41	89	150	146
Accounts receivable, net
Customer		1,792	1,298
Unamortized energy contract assets		38	38
Inventory, net
Materials and supplies		973	978
Assets held for sale		11	958
Other current assets		1,290	1,357
Total current assets		6,740	6,947
Property, plant and equipment, net		21,311	22,214
NDT funds		14,688	14,464
Unamortized energy contract assets		285	293
Other Assets, Noncurrent		1,835	1,826
Total assets	[2]	47,326	48,094
Long-term debt due within one year		699	197
Accounts payable		1,529	1,253
Accrued expenses		692	788
Unamortized energy contract liabilities		5	7
Liabilities held for sale		3	375
Other		371	444
Total current liabilities		6,298	5,219
Long-term debt		5,038	5,566
Asset retirement obligations, noncurrent		12,157	12,054
Unamortized energy contract liabilities		3	3
Other		1,405	1,308
Total liabilities	[2]	33,886	33,418
Exelon Generation Co L L C [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Cash and cash equivalents		175	98
Restricted cash and cash equivalents		33	44
Accounts receivable, net
Customer		145	148
Other		35	36
Unamortized energy contract assets		22	22
Inventory, net
Materials and supplies		242	244
Assets held for sale		0	101
Other current assets		443	669
Total current assets		1,095	1,362
Property, plant and equipment, net		5,747	5,803
NDT funds		3,089	3,007
Unamortized energy contract assets		243	249
Other Assets, Noncurrent		38	42
Total noncurrent assets		9,117	9,101
Total assets		10,212	10,463
Long-term debt due within one year		69	68
Accounts payable		95	81
Accrued expenses		67	70
Unamortized energy contract liabilities		3	4
Liabilities held for sale		0	16
Other		1	5
Total current liabilities		235	244
Long-term debt		861	889
Asset retirement obligations, noncurrent		2,347	2,318
Other		116	129
Total noncurrent liabilities		3,324	3,336
Total liabilities		3,559	3,580
PP&E - unrestricted asset		1	1
Other Assets		0	9
Exelon Generation Co L L C [Member] | Exelon Generation Co L L C [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Inventory, net
Unamortized energy contract assets		222
Exelon Generation Co L L C [Member] | Recourse [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Inventory, net
Total liabilities		2	8
Pepco Holdings LLC [Member]
Variable Interest Entity [Line Items]
Cash and cash equivalents		558	111	49	131
Restricted cash and cash equivalents		37	39	37	36
Accounts receivable, net
Customer		456	525
Inventory, net
Materials and supplies		196	198
Other current assets		52	45
Total current assets		1,976	1,599
Property, plant and equipment, net		15,651	15,377
Other Assets, Noncurrent		310	307
Total assets	[3]	24,387	23,736
Long-term debt due within one year		304	347
Accounts payable		503	539
Accrued expenses		279	299
Unamortized energy contract liabilities		92	92
Other		137	141
Total current liabilities		1,643	2,154
Long-term debt		7,273	6,659
Asset retirement obligations, noncurrent		59	59
Unamortized energy contract liabilities		214	235
Other		595	622
Total liabilities	[3]	13,736	13,692
Pepco Holdings LLC [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Cash and cash equivalents		0	0
Restricted cash and cash equivalents		4	3
Accounts receivable, net
Customer		0	0
Other		0	0
Unamortized energy contract assets		0	0
Inventory, net
Materials and supplies		0	0
Assets held for sale		0	0
Other current assets		5	5
Total current assets		9	8
Property, plant and equipment, net		0	0
NDT funds		0	0
Unamortized energy contract assets		0	0
Other Assets, Noncurrent		9	10
Total noncurrent assets		9	10
Total assets		18	18
Long-term debt due within one year		21	26
Accounts payable		0	0
Accrued expenses		0	0
Unamortized energy contract liabilities		0	0
Liabilities held for sale		0	0
Other		0	0
Total current liabilities		21	26
Long-term debt		0	0
Asset retirement obligations, noncurrent		0	0
Other		0	0
Total noncurrent liabilities		0	0
Total liabilities		21	26
Atlantic City Electric Company [Member]
Variable Interest Entity [Line Items]
Cash and cash equivalents		353	17	8	12
Restricted cash and cash equivalents		4	3	$ 3	$ 2
Accounts receivable, net
Customer		111	124
Inventory, net
Other current assets		2	3
Total current assets		631	326
Property, plant and equipment, net		3,552	3,475
Other Assets, Noncurrent		50	50
Total assets	[4]	4,679	4,286
Long-term debt due within one year		218	261
Accounts payable		162	177
Accrued expenses		48	46
Other		9	11
Total current liabilities		526	780
Long-term debt		1,500	1,152
Other		48	48
Total liabilities	[4]	2,985	2,895
Atlantic City Electric Company [Member] | Variable Interest Entity, Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Cash and cash equivalents		0	0
Restricted cash and cash equivalents		4	3
Accounts receivable, net
Customer		0	0
Other		0	0
Unamortized energy contract assets		0	0
Inventory, net
Materials and supplies		0	0
Assets held for sale		0	0
Other current assets		0	0
Total current assets		4	3
Property, plant and equipment, net		0	0
NDT funds		0	0
Unamortized energy contract assets		0	0
Other Assets, Noncurrent		9	10
Total noncurrent assets		9	10
Total assets		13	13
Long-term debt due within one year		16	21
Accounts payable		0	0
Accrued expenses		0	0
Unamortized energy contract liabilities		0	0
Liabilities held for sale		0	0
Other		0	0
Total current liabilities		16	21
Long-term debt		0	0
Asset retirement obligations, noncurrent		0	0
Other		0	0
Total noncurrent liabilities		0	0
Total liabilities		$ 16	$ 21

[1] Exelon’s consolidated assets include $9,985 million and $10,200 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,578 million and $3,598 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 16 — Variable Interest Entities for additional information.

[2] Generation’s consolidated assets include $9,967 million and $10,182 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,557 million and $3,572 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 16 — Variable Interest Entities for additional information.

[3] PHI’s consolidated total assets include $18 million at both March 31, 2021 and December 31, 2020 of PHI's consolidated VIE that can only be used to settle the liabilities of the VIE. PHI’s consolidated total liabilities include $21 million and $26 million at March 31, 2021 and December 31, 2020, respectively, of PHI's consolidated VIE for which the VIE creditors do not have recourse to PHI. See Note 16 — Variable Interest Entities for additional information.

[4] ACE’s consolidated total assets include $13 million at both March 31, 2021 and December 31, 2020, of ACE's consolidated VIE that can only be used to settle the liabilities of the VIE. ACE’s consolidated total liabilities include $16 million and $21 million at March 31, 2021 and December 31, 2020, respectively, of ACE's consolidated VIE for which the VIE creditors do not have recourse to ACE. See Note 16 — Variable Interest Entities for additional information.

XML

Variable Interest Entities - Summary of Significant Unconsolidated VIEs (Details) - USD ($) $ in Millions		Mar. 31, 2021	Dec. 31, 2020
Variable Interest Entity [Line Items]
Total assets	[1]	$ 130,000	$ 129,317
Total liabilities	[1]	95,687	94,449
Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Total assets		1,175	1,178
Total liabilities		313	284
Exelon's ownership interest in VIE		150	157
Other ownership interests in VIE		712	737
Exelon Generation Co L L C [Member]
Variable Interest Entity [Line Items]
Total assets	[2]	47,326	48,094
Total liabilities	[2]	33,886	33,418
Exelon Generation Co L L C [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Total assets		1,175	1,178
Total liabilities		313	284
Exelon's ownership interest in VIE		150	157
Other ownership interests in VIE		712	737
Commercial Agreement VIE [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Total assets		789	777
Total liabilities		95	61
Exelon's ownership interest in VIE		0	0
Other ownership interests in VIE		694	716
Commercial Agreement VIE [Member] | Exelon Generation Co L L C [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Total assets		789	777
Total liabilities		95	61
Exelon's ownership interest in VIE		0	0
Other ownership interests in VIE		694	716
Equity Investment VIE [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Total assets		386	401
Total liabilities		218	223
Exelon's ownership interest in VIE		150	157
Other ownership interests in VIE		18	21
Equity Investment VIE [Member] | Exelon Generation Co L L C [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Total assets		386	401
Total liabilities		218	223
Exelon's ownership interest in VIE		150	157
Other ownership interests in VIE		$ 18	$ 21

[1] Exelon’s consolidated assets include $9,985 million and $10,200 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Exelon’s consolidated liabilities include $3,578 million and $3,598 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs for which the VIE creditors do not have recourse to Exelon. See Note 16 — Variable Interest Entities for additional information.

[2] Generation’s consolidated assets include $9,967 million and $10,182 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs that can only be used to settle the liabilities of the VIE. Generation’s consolidated liabilities include $3,557 million and $3,572 million at March 31, 2021 and December 31, 2020, respectively, of certain VIEs for which the VIE creditors do not have recourse to Generation. See Note 16 — Variable Interest Entities for additional information.

XML

Supplemental Financial Information - Operations (Detail) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Supplemental Statement of Operations Information [Line Items]
Operating lease income	$ 4	$ 5
Variable lease income	64	69
Decommissioning-Related Activities [Abstract]
Net realized income on NDT funds - Regulatory agreement units	291	47
Net realized income on NDT funds - Non-regulatory agreement units	203	82
Net unrealized gains on NDT funds - Regulatory agreement units	(82)	(932)
Net unrealized gains on NDT funds - Non-regulatory agreement units	(66)	(706)
Regulatory offset to NDT fund-related activities	(167)	709
Decommissioning-related activities	179	(800)
AFUDC - Equity	28	23
Non-service net periodic benefit cost	20	10
Exelon Generation Co L L C [Member]
Supplemental Statement of Operations Information [Line Items]
Operating lease income	3	3
Variable lease income	64	69
Decommissioning-Related Activities [Abstract]
Net realized income on NDT funds - Regulatory agreement units	291	47
Net realized income on NDT funds - Non-regulatory agreement units	203	82
Net unrealized gains on NDT funds - Regulatory agreement units	(82)	(932)
Net unrealized gains on NDT funds - Non-regulatory agreement units	(66)	(706)
Regulatory offset to NDT fund-related activities	(167)	709
Decommissioning-related activities	179	(800)
AFUDC - Equity	0	0
Non-service net periodic benefit cost	0	0
Commonwealth Edison Co [Member]
Decommissioning-Related Activities [Abstract]
Net realized income on NDT funds - Regulatory agreement units	0	0
Net realized income on NDT funds - Non-regulatory agreement units	0	0
Net unrealized gains on NDT funds - Regulatory agreement units	0	0
Net unrealized gains on NDT funds - Non-regulatory agreement units	0	0
Regulatory offset to NDT fund-related activities	0	0
Decommissioning-related activities	0	0
AFUDC - Equity	4	6
Non-service net periodic benefit cost	0	0
PECO Energy Co [Member]
Decommissioning-Related Activities [Abstract]
Net realized income on NDT funds - Regulatory agreement units	0	0
Net realized income on NDT funds - Non-regulatory agreement units	0	0
Net unrealized gains on NDT funds - Regulatory agreement units	0	0
Net unrealized gains on NDT funds - Non-regulatory agreement units	0	0
Regulatory offset to NDT fund-related activities	0	0
Decommissioning-related activities	0	0
AFUDC - Equity	6	3
Non-service net periodic benefit cost	0	0
Baltimore Gas and Electric Company [Member]
Decommissioning-Related Activities [Abstract]
Net realized income on NDT funds - Regulatory agreement units	0	0
Net realized income on NDT funds - Non-regulatory agreement units	0	0
Net unrealized gains on NDT funds - Regulatory agreement units	0	0
Net unrealized gains on NDT funds - Non-regulatory agreement units	0	0
Regulatory offset to NDT fund-related activities	0	0
Decommissioning-related activities	0	0
AFUDC - Equity	7	5
Non-service net periodic benefit cost	0	0
Pepco Holdings LLC [Member]
Supplemental Statement of Operations Information [Line Items]
Operating lease income	1	1
Variable lease income	0	0
Decommissioning-Related Activities [Abstract]
Net realized income on NDT funds - Regulatory agreement units	0	0
Net realized income on NDT funds - Non-regulatory agreement units	0	0
Net unrealized gains on NDT funds - Regulatory agreement units	0	0
Net unrealized gains on NDT funds - Non-regulatory agreement units	0	0
Regulatory offset to NDT fund-related activities	0	0
Decommissioning-related activities	0	0
AFUDC - Equity	11	9
Non-service net periodic benefit cost	0	0
Potomac Electric Power Company [Member]
Decommissioning-Related Activities [Abstract]
Net realized income on NDT funds - Regulatory agreement units	0	0
Net realized income on NDT funds - Non-regulatory agreement units	0	0
Net unrealized gains on NDT funds - Regulatory agreement units	0	0
Net unrealized gains on NDT funds - Non-regulatory agreement units	0	0
Regulatory offset to NDT fund-related activities	0	0
Decommissioning-related activities	0	0
AFUDC - Equity	9	6
Non-service net periodic benefit cost	0	0
Delmarva Power and Light Company [Member]
Supplemental Statement of Operations Information [Line Items]
Operating lease income	1	1
Variable lease income	0	0
Decommissioning-Related Activities [Abstract]
Net realized income on NDT funds - Regulatory agreement units	0	0
Net realized income on NDT funds - Non-regulatory agreement units	0	0
Net unrealized gains on NDT funds - Regulatory agreement units	0	0
Net unrealized gains on NDT funds - Non-regulatory agreement units	0	0
Regulatory offset to NDT fund-related activities	0	0
Decommissioning-related activities	0	0
AFUDC - Equity	1	1
Non-service net periodic benefit cost	0	0
Atlantic City Electric Company [Member]
Decommissioning-Related Activities [Abstract]
Net realized income on NDT funds - Regulatory agreement units	0	0
Net realized income on NDT funds - Non-regulatory agreement units	0	0
Net unrealized gains on NDT funds - Regulatory agreement units	0	0
Net unrealized gains on NDT funds - Non-regulatory agreement units	0	0
Regulatory offset to NDT fund-related activities	0	0
Decommissioning-related activities	0	0
AFUDC - Equity	1	2
Non-service net periodic benefit cost	$ 0	$ 0

XML

Supplemental Financial Information - Taxes Other Than Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Supplemental Statement of Operations Information [Line Items]
Utility taxes	$ 217	$ 218
Property	154	150
Payroll	61	63
Exelon Generation Co L L C [Member]
Supplemental Statement of Operations Information [Line Items]
Utility taxes	24	26
Property	68	69
Payroll	28	31
Commonwealth Edison Co [Member]
Supplemental Statement of Operations Information [Line Items]
Utility taxes	59	60
Property	8	7
Payroll	7	7
PECO Energy Co [Member]
Supplemental Statement of Operations Information [Line Items]
Utility taxes	35	31
Property	4	4
Payroll	4	4
Baltimore Gas and Electric Company [Member]
Supplemental Statement of Operations Information [Line Items]
Utility taxes	25	26
Property	42	39
Payroll	5	4
Pepco Holdings LLC [Member]
Supplemental Statement of Operations Information [Line Items]
Utility taxes	74	75
Property	32	31
Payroll	7	8
Potomac Electric Power Company [Member]
Supplemental Statement of Operations Information [Line Items]
Utility taxes	67	69
Property	21	21
Payroll	2	2
Delmarva Power and Light Company [Member]
Supplemental Statement of Operations Information [Line Items]
Utility taxes	6	6
Property	10	9
Payroll	1	1
Atlantic City Electric Company [Member]
Supplemental Statement of Operations Information [Line Items]
Utility taxes	1	0
Property	1	1
Payroll	$ 0	$ 1

XML

Supplemental Financial Information - Cash Flow (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Depreciation, Amortization and Accretion [Abstract]
Property, plant and equipment	$ 1,522	$ 856
Amortization of regulatory assets	160	149
Amortization of intangible assets, net	15	16
Amortization of energy contract assets and liabilities	4	2
Nuclear fuel	276	231
ARO accretion	127	124
Total depreciation, amortization and accretion	2,104	1,378
Other Non-Cash Operating Activities [Abstract]
Pension and non-pension postretirement benefit costs	95	98
Allowance for credit losses	85	45
Other decommissioning-related activity	(322)	128
Energy-related options	17	6
True-up adjustments to decoupling mechanisms and formula rates	(129)	(71)
Long-term incentive plan	32	(7)
Amortization of operating ROU asset	37	51
AFUDC - Equity	28	23
Return on borrowed funds
Other Non-Cash Operating Activities [Abstract]
AFUDC - Equity	(28)	(23)
Exelon Generation Co L L C [Member]
Depreciation, Amortization and Accretion [Abstract]
Property, plant and equipment	928	290
Amortization of regulatory assets	0	0
Amortization of intangible assets, net	12	14
Amortization of energy contract assets and liabilities	3	2
Nuclear fuel	276	231
ARO accretion	127	124
Total depreciation, amortization and accretion	1,346	661
Other Non-Cash Operating Activities [Abstract]
Pension and non-pension postretirement benefit costs	26	27
Allowance for credit losses	34	4
Other decommissioning-related activity	(332)	128
Energy-related options	17	6
True-up adjustments to decoupling mechanisms and formula rates	0	0
Long-term incentive plan	0	0
Amortization of operating ROU asset	21	35
AFUDC - Equity	0	0
Exelon Generation Co L L C [Member] | Return on borrowed funds
Other Non-Cash Operating Activities [Abstract]
AFUDC - Equity	0	0
Commonwealth Edison Co [Member]
Depreciation, Amortization and Accretion [Abstract]
Property, plant and equipment	239	228
Amortization of regulatory assets	53	45
Amortization of intangible assets, net	0	0
Amortization of energy contract assets and liabilities	0	0
Nuclear fuel	0	0
ARO accretion	0	0
Total depreciation, amortization and accretion	292	273
Other Non-Cash Operating Activities [Abstract]
Pension and non-pension postretirement benefit costs	32	28
Allowance for credit losses	13	7
Other decommissioning-related activity	0	0
Energy-related options	0	0
True-up adjustments to decoupling mechanisms and formula rates	(54)	(17)
Long-term incentive plan	0	0
Amortization of operating ROU asset	0	0
AFUDC - Equity	4	6
Commonwealth Edison Co [Member] | Return on borrowed funds
Other Non-Cash Operating Activities [Abstract]
AFUDC - Equity	(4)	(6)
PECO Energy Co [Member]
Depreciation, Amortization and Accretion [Abstract]
Property, plant and equipment	82	79
Amortization of regulatory assets	4	7
Amortization of intangible assets, net	0	0
Amortization of energy contract assets and liabilities	0	0
Nuclear fuel	0	0
ARO accretion	0	0
Total depreciation, amortization and accretion	86	86
Other Non-Cash Operating Activities [Abstract]
Pension and non-pension postretirement benefit costs	2	1
Allowance for credit losses	24	17
Other decommissioning-related activity	0	0
Energy-related options	0	0
True-up adjustments to decoupling mechanisms and formula rates	(10)	0
Long-term incentive plan	0	0
Amortization of operating ROU asset	0	0
AFUDC - Equity	6	3
PECO Energy Co [Member] | Return on borrowed funds
Other Non-Cash Operating Activities [Abstract]
AFUDC - Equity	(6)	(3)
Baltimore Gas and Electric Company [Member]
Depreciation, Amortization and Accretion [Abstract]
Property, plant and equipment	106	97
Amortization of regulatory assets	46	46
Amortization of intangible assets, net	0	0
Amortization of energy contract assets and liabilities	0	0
Nuclear fuel	0	0
ARO accretion	0	0
Total depreciation, amortization and accretion	152	143
Other Non-Cash Operating Activities [Abstract]
Pension and non-pension postretirement benefit costs	14	15
Allowance for credit losses	4	7
Other decommissioning-related activity	0	0
Energy-related options	0	0
True-up adjustments to decoupling mechanisms and formula rates	(18)	(35)
Long-term incentive plan	0	0
Amortization of operating ROU asset	7	8
AFUDC - Equity	7	5
Baltimore Gas and Electric Company [Member] | Return on borrowed funds
Other Non-Cash Operating Activities [Abstract]
AFUDC - Equity	(7)	(5)
Pepco Holdings LLC [Member]
Depreciation, Amortization and Accretion [Abstract]
Property, plant and equipment	154	144
Amortization of regulatory assets	56	50
Amortization of intangible assets, net	0	0
Amortization of energy contract assets and liabilities	0	0
Nuclear fuel	0	0
ARO accretion	0	0
Total depreciation, amortization and accretion	210	194
Other Non-Cash Operating Activities [Abstract]
Pension and non-pension postretirement benefit costs	12	17
Allowance for credit losses	10	10
Other decommissioning-related activity	0	0
Energy-related options	0	0
True-up adjustments to decoupling mechanisms and formula rates	(46)	(19)
Long-term incentive plan	0	0
Amortization of operating ROU asset	7	5
AFUDC - Equity	11	9
Pepco Holdings LLC [Member] | Return on borrowed funds
Other Non-Cash Operating Activities [Abstract]
AFUDC - Equity	(11)	(9)
Potomac Electric Power Company [Member]
Depreciation, Amortization and Accretion [Abstract]
Property, plant and equipment	67	64
Amortization of regulatory assets	35	31
Amortization of intangible assets, net	0	0
Amortization of energy contract assets and liabilities	0	0
Nuclear fuel	0	0
ARO accretion	0	0
Total depreciation, amortization and accretion	102	95
Other Non-Cash Operating Activities [Abstract]
Pension and non-pension postretirement benefit costs	2	3
Allowance for credit losses	5	4
Other decommissioning-related activity	0	0
Energy-related options	0	0
True-up adjustments to decoupling mechanisms and formula rates	(26)	(15)
Long-term incentive plan	0	0
Amortization of operating ROU asset	1	2
AFUDC - Equity	9	6
Potomac Electric Power Company [Member] | Return on borrowed funds
Other Non-Cash Operating Activities [Abstract]
AFUDC - Equity	(9)	(6)
Delmarva Power and Light Company [Member]
Depreciation, Amortization and Accretion [Abstract]
Property, plant and equipment	42	38
Amortization of regulatory assets	11	10
Amortization of intangible assets, net	0	0
Amortization of energy contract assets and liabilities	0	0
Nuclear fuel	0	0
ARO accretion	0	0
Total depreciation, amortization and accretion	53	48
Other Non-Cash Operating Activities [Abstract]
Pension and non-pension postretirement benefit costs	1	1
Allowance for credit losses	4	3
Other decommissioning-related activity	0	0
Energy-related options	0	0
True-up adjustments to decoupling mechanisms and formula rates	(9)	(4)
Long-term incentive plan	0	0
Amortization of operating ROU asset	3	2
AFUDC - Equity	1	1
Delmarva Power and Light Company [Member] | Return on borrowed funds
Other Non-Cash Operating Activities [Abstract]
AFUDC - Equity	(1)	(1)
Atlantic City Electric Company [Member]
Depreciation, Amortization and Accretion [Abstract]
Property, plant and equipment	37	34
Amortization of regulatory assets	10	9
Amortization of intangible assets, net	0	0
Amortization of energy contract assets and liabilities	0	0
Nuclear fuel	0	0
ARO accretion	0	0
Total depreciation, amortization and accretion	47	43
Other Non-Cash Operating Activities [Abstract]
Pension and non-pension postretirement benefit costs	3	3
Allowance for credit losses	1	3
Other decommissioning-related activity	0	0
Energy-related options	0	0
True-up adjustments to decoupling mechanisms and formula rates	(11)	0
Long-term incentive plan	0	0
Amortization of operating ROU asset	1	1
AFUDC - Equity	1	2
Atlantic City Electric Company [Member] | Return on borrowed funds
Other Non-Cash Operating Activities [Abstract]
AFUDC - Equity	$ (1)	$ (2)

XML

Supplemental Financial Information - Balance Sheet (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	$ 1,908	$ 663	$ 1,457	$ 587
Restricted cash	374	438	414	358
Restricted cash included in other long-term assets	52	53	121	177
Total cash, restricted cash, and cash equivalents	2,334	1,166	1,992	1,122
Accrued Expenses [Abstract]
Compensation-related accruals	581	1,069
Taxes accrued	540	527
Interest accrued	424	331
Held for Sale
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Total cash, restricted cash, and cash equivalents		12
Exelon Generation Co L L C [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	721	226	821	303
Restricted cash	41	89	150	146
Restricted cash included in other long-term assets	0	0	0	0
Total cash, restricted cash, and cash equivalents	762	327	971	449
Accrued Expenses [Abstract]
Compensation-related accruals	210	426
Taxes accrued	279	229
Interest accrued	76	44
Exelon Generation Co L L C [Member] | Held for Sale
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Total cash, restricted cash, and cash equivalents		12
Commonwealth Edison Co [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	86	83	514	90
Restricted cash	270	279	211	150
Restricted cash included in other long-term assets	43	43	108	163
Total cash, restricted cash, and cash equivalents	399	405	833	403
Accrued Expenses [Abstract]
Compensation-related accruals	91	170
Taxes accrued	70	94
Interest accrued	65	109
Commonwealth Edison Co [Member] | Held for Sale
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Total cash, restricted cash, and cash equivalents		0
PECO Energy Co [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	48	19	31	21
Restricted cash	7	7	7	6
Restricted cash included in other long-term assets	0	0	0	0
Total cash, restricted cash, and cash equivalents	55	26	38	27
Accrued Expenses [Abstract]
Compensation-related accruals	42	73
Taxes accrued	18	16
Interest accrued	36	37
PECO Energy Co [Member] | Held for Sale
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Total cash, restricted cash, and cash equivalents		0
Baltimore Gas and Electric Company [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	21	144	11	24
Restricted cash	1	1	1	1
Restricted cash included in other long-term assets	0	0	0	0
Total cash, restricted cash, and cash equivalents	22	145	12	25
Accrued Expenses [Abstract]
Compensation-related accruals	49	84
Taxes accrued	50	73
Interest accrued	41	46
Baltimore Gas and Electric Company [Member] | Held for Sale
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Total cash, restricted cash, and cash equivalents		0
Pepco Holdings LLC [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	558	111	49	131
Restricted cash	37	39	37	36
Restricted cash included in other long-term assets	9	10	12	14
Total cash, restricted cash, and cash equivalents	604	160	98	181
Accrued Expenses [Abstract]
Compensation-related accruals	73	109
Taxes accrued	108	117
Interest accrued	79	51
Pepco Holdings LLC [Member] | Held for Sale
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Total cash, restricted cash, and cash equivalents		0
Potomac Electric Power Company [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	134	30	18	30
Restricted cash	33	35	33	33
Restricted cash included in other long-term assets	0	0	0	0
Total cash, restricted cash, and cash equivalents	167	65	51	63
Accrued Expenses [Abstract]
Compensation-related accruals	26	36
Taxes accrued	92	90
Interest accrued	37	26
Potomac Electric Power Company [Member] | Held for Sale
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Total cash, restricted cash, and cash equivalents		0
Delmarva Power and Light Company [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	64	15	7	13
Restricted cash	0	0	0	0
Restricted cash included in other long-term assets	0	0	0	0
Total cash, restricted cash, and cash equivalents	64	15	7	13
Accrued Expenses [Abstract]
Compensation-related accruals	15	18
Taxes accrued	10	18
Interest accrued	20	7
Delmarva Power and Light Company [Member] | Held for Sale
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Total cash, restricted cash, and cash equivalents		0
Atlantic City Electric Company [Member]
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Cash and cash equivalents	353	17	8	12
Restricted cash	4	3	3	2
Restricted cash included in other long-term assets	9	10	12	14
Total cash, restricted cash, and cash equivalents	366	30	$ 23	$ 28
Accrued Expenses [Abstract]
Compensation-related accruals	12	17
Taxes accrued	12	12
Interest accrued	$ 20	12
Atlantic City Electric Company [Member] | Held for Sale
Cash, Cash Equivalents, Restricted Cash and Restricted Cash Equivalents [Abstract]
Total cash, restricted cash, and cash equivalents		$ 0

XML

Related Party Transactions - Operating Revenues and Purchased Power and Fuel (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Related Party Transaction [Line Items]
Revenue from Related Parties	$ 0	$ 1
Exelon Generation Co L L C [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	295	330
Purchased power and/or fuel from affiliates	0	(6)
Exelon Generation Co L L C [Member] | Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	78	90
Purchased power and/or fuel from affiliates	6	7
Exelon Generation Co L L C [Member] | PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	42	37
Exelon Generation Co L L C [Member] | Baltimore Gas And Electric Company Affiliate [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	72	99
Exelon Generation Co L L C [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	100	103
Exelon Generation Co L L C [Member] | Potomac Electric Power Co Affiliate [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	75	79
Exelon Generation Co L L C [Member] | Delmarva Power and Light Co Affiliate [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	21	22
Exelon Generation Co L L C [Member] | Atlantic City Electric Co Affiliate [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	4	2
Exelon Generation Co L L C [Member] | Exelon Business Services Co Affiliate [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	3	1
Commonwealth Edison Co [Member]
Related Party Transaction [Line Items]
Revenue from Related Parties	6	5
Purchased power and/or fuel from affiliates	85	97
Commonwealth Edison Co [Member] | Exelon Generation Co LLC Affiliate [Member]
Related Party Transaction [Line Items]
Purchased power and/or fuel from affiliates	$ 84	$ 97

XML

Related Party Transactions - BSC and PHISCO Service Companies (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2021	Mar. 31, 2020
Exelon Business Services Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction Capitalized Costs Support Services	$ 124	$ 113
PHI Service Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction Capitalized Costs Support Services	17	14
Exelon Generation Co L L C [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	145	142
Exelon Generation Co L L C [Member] | Exelon Business Services Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	144	140
Related Party Transaction Capitalized Costs Support Services	10	11
Commonwealth Edison Co [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	71	74
Commonwealth Edison Co [Member] | Exelon Business Services Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	71	72
Related Party Transaction Capitalized Costs Support Services	45	42
PECO Energy Co [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	41	38
PECO Energy Co [Member] | Exelon Business Services Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	39	37
Related Party Transaction Capitalized Costs Support Services	17	16
Baltimore Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	45	42
Baltimore Gas and Electric Company [Member] | Exelon Business Services Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	43	41
Related Party Transaction Capitalized Costs Support Services	20	28
Pepco Holdings LLC [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	40	38
Pepco Holdings LLC [Member] | Exelon Business Services Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	39	37
Related Party Transaction Capitalized Costs Support Services	32	16
Pepco Holdings LLC [Member] | PHI Service Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	0	0
Related Party Transaction Capitalized Costs Support Services	17	14
Potomac Electric Power Company [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	52	51
Potomac Electric Power Company [Member] | Exelon Business Services Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	22	21
Related Party Transaction Capitalized Costs Support Services	13	6
Potomac Electric Power Company [Member] | PHI Service Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	30	30
Related Party Transaction Capitalized Costs Support Services	7	6
Delmarva Power and Light Company [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	39	37
Delmarva Power and Light Company [Member] | Exelon Business Services Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	14	13
Related Party Transaction Capitalized Costs Support Services	10	5
Delmarva Power and Light Company [Member] | PHI Service Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	25	24
Related Party Transaction Capitalized Costs Support Services	5	4
Atlantic City Electric Company [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	34	33
Atlantic City Electric Company [Member] | Exelon Business Services Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	12	11
Related Party Transaction Capitalized Costs Support Services	8	4
Atlantic City Electric Company [Member] | PHI Service Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Expenses from Transactions with Related Party	22	22
Related Party Transaction Capitalized Costs Support Services	$ 5	$ 4

XML

Related Party Transactions - Current Receivables From/Payables To Affiliates (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	$ 441	$ 544
Accounts Payable, Related Parties, Current	5	5
Exelon Generation Co L L C [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	125	107
Accounts Receivable, Related Parties, Current	106	153
Exelon Generation Co L L C [Member] | Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	50	78
Due to Related Parties, Current	24	50
Exelon Generation Co L L C [Member] | PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	15	17
Exelon Generation Co L L C [Member] | Baltimore Gas And Electric Company Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	11	11
Exelon Generation Co L L C [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Exelon Generation Co L L C [Member] | Potomac Electric Power Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	12	13
Exelon Generation Co L L C [Member] | Delmarva Power and Light Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	2	3
Exelon Generation Co L L C [Member] | Atlantic City Electric Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	8	6
Exelon Generation Co L L C [Member] | Other Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	8	25
Commonwealth Edison Co [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	80	96
Accounts Receivable, Related Parties, Current	21	22
Commonwealth Edison Co [Member] | Exelon Generation Co LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	17	13
Accounts Payable, Related Parties, Current	26	28
Commonwealth Edison Co [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	104	146
Commonwealth Edison Co [Member] | PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	1
Commonwealth Edison Co [Member] | Baltimore Gas And Electric Company Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	1	0
Commonwealth Edison Co [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	1	0
Commonwealth Edison Co [Member] | Potomac Electric Power Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	1	2
Commonwealth Edison Co [Member] | Delmarva Power and Light Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	1
Commonwealth Edison Co [Member] | Atlantic City Electric Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Commonwealth Edison Co [Member] | Other Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	1	5
PECO Energy Co [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	46	50
Accounts Receivable, Related Parties, Current	0	2
PECO Energy Co [Member] | Exelon Generation Co LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PECO Energy Co [Member] | Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PECO Energy Co [Member] | Baltimore Gas And Electric Company Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PECO Energy Co [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PECO Energy Co [Member] | Potomac Electric Power Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PECO Energy Co [Member] | Delmarva Power and Light Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PECO Energy Co [Member] | Atlantic City Electric Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PECO Energy Co [Member] | Other Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	2
Baltimore Gas and Electric Company [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	43	61
Accounts Receivable, Related Parties, Current	0	3
Baltimore Gas and Electric Company [Member] | Exelon Generation Co LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Baltimore Gas and Electric Company [Member] | Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Baltimore Gas and Electric Company [Member] | PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Baltimore Gas and Electric Company [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Baltimore Gas and Electric Company [Member] | Potomac Electric Power Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	1
Baltimore Gas and Electric Company [Member] | Delmarva Power and Light Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Baltimore Gas and Electric Company [Member] | Atlantic City Electric Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Baltimore Gas and Electric Company [Member] | Other Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	2
Pepco Holdings LLC [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	78	104
Accounts Receivable, Related Parties, Current	0	8
Pepco Holdings LLC [Member] | Affiliated Entity [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	18	15
Potomac Electric Power Company [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	44	55
Accounts Receivable, Related Parties, Current	0	2
Potomac Electric Power Company [Member] | Exelon Generation Co LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Potomac Electric Power Company [Member] | Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Potomac Electric Power Company [Member] | PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Potomac Electric Power Company [Member] | Baltimore Gas And Electric Company Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Potomac Electric Power Company [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Potomac Electric Power Company [Member] | Delmarva Power and Light Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Potomac Electric Power Company [Member] | Atlantic City Electric Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Potomac Electric Power Company [Member] | Other Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	2
Delmarva Power and Light Company [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	24	36
Accounts Receivable, Related Parties, Current	0	1
Delmarva Power and Light Company [Member] | Exelon Generation Co LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Delmarva Power and Light Company [Member] | Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Delmarva Power and Light Company [Member] | PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Delmarva Power and Light Company [Member] | Baltimore Gas And Electric Company Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Delmarva Power and Light Company [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Delmarva Power and Light Company [Member] | Potomac Electric Power Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Delmarva Power and Light Company [Member] | Atlantic City Electric Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Delmarva Power and Light Company [Member] | Other Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	1
Atlantic City Electric Company [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	27	31
Accounts Receivable, Related Parties, Current	1	6
Atlantic City Electric Company [Member] | Exelon Generation Co LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Atlantic City Electric Company [Member] | Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Atlantic City Electric Company [Member] | PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Atlantic City Electric Company [Member] | Baltimore Gas And Electric Company Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Atlantic City Electric Company [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Atlantic City Electric Company [Member] | Potomac Electric Power Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Atlantic City Electric Company [Member] | Delmarva Power and Light Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Atlantic City Electric Company [Member] | Other Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	1	6
Business Services Company [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	229	271
Business Services Company [Member] | Exelon Generation Co LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	84	72
Business Services Company [Member] | Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	49	59
Business Services Company [Member] | PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	24	28
Business Services Company [Member] | Baltimore Gas And Electric Company Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	30	47
Business Services Company [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	7	4
Business Services Company [Member] | Potomac Electric Power Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	16	25
Business Services Company [Member] | Delmarva Power and Light Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	11	21
Business Services Company [Member] | Atlantic City Electric Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	8	15
Business Services Company [Member] | Other Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PHI Service Company [Member]
Related Party Transaction [Line Items]
Accounts Receivable, Related Parties, Current	35	33
PHI Service Company [Member] | Exelon Generation Co LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PHI Service Company [Member] | Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PHI Service Company [Member] | PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PHI Service Company [Member] | Baltimore Gas And Electric Company Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PHI Service Company [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
PHI Service Company [Member] | Potomac Electric Power Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	14	14
PHI Service Company [Member] | Delmarva Power and Light Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	11	10
PHI Service Company [Member] | Atlantic City Electric Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	10	9
PHI Service Company [Member] | Other Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	0
Other Legal Entities [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Current	10	43
Accounts Receivable, Related Parties, Current	49	51
Other Legal Entities [Member] | Exelon Generation Co LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	24	22
Other Legal Entities [Member] | Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	5	9
Other Legal Entities [Member] | PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	7	4
Other Legal Entities [Member] | Baltimore Gas And Electric Company Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	1	3
Other Legal Entities [Member] | Pepco Holdings LLC Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	10	11
Other Legal Entities [Member] | Potomac Electric Power Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	1	0
Other Legal Entities [Member] | Delmarva Power and Light Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	0	1
Other Legal Entities [Member] | Atlantic City Electric Co Affiliate [Member]
Related Party Transaction [Line Items]
Related Party Transaction, Due from (to) Related Party, Current	$ 1	$ 1

XML

Related Party Transactions - Noncurrent Receivables from/Payables to affiliates (Details) - Exelon Generation Co L L C [Member] - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Noncurrent	$ 2,865	$ 3,017
Commonwealth Edison Co Affiliate [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Noncurrent	2,375	2,541
PECO Energy Co Affiliate [Member]
Related Party Transaction [Line Items]
Accounts Payable, Related Parties, Noncurrent	$ 490	$ 475

XML

Related Party Transactions - Long Term Debt to Financing Trusts (Details) - USD ($) $ in Millions	Mar. 31, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
Long-term debt to financing trust	$ 390	$ 390
ComEd Financing Three Affiliate [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	206	206
PECO Trust Three Affiliate [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	81	81
PECO Trust Four Affiliate [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	103	103
Commonwealth Edison Co [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	205	205
Commonwealth Edison Co [Member] | ComEd Financing Three Affiliate [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	205	205
Commonwealth Edison Co [Member] | PECO Trust Three Affiliate [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	0	0
Commonwealth Edison Co [Member] | PECO Trust Four Affiliate [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	0	0
PECO Energy Co [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	184	184
PECO Energy Co [Member] | ComEd Financing Three Affiliate [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	0	0
PECO Energy Co [Member] | PECO Trust Three Affiliate [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	81	81
PECO Energy Co [Member] | PECO Trust Four Affiliate [Member]
Related Party Transaction [Line Items]
Long-term debt to financing trust	$ 103	$ 103